Method, device and computer equipment for determining wellbore temperature parameters

Abstract

The present application provides a method, device and computer equipment for determining wellbore temperature parameters, belonging to the field of oil and gas engineering technology. The method includes: determining multiple well sections of the target wellbore to be studied, the multiple well sections are well sections divided sequentially from the bottom of the target wellbore to the wellhead; determining multiple time steps of the target wellbore, the multiple time steps are time periods obtained by dividing the production time of the target wellbore in sequence; for each time step of each well section, obtaining the first time step parameter of the well section in the time step; obtaining the well temperature relationship data of the target well area where the target wellbore is located, the well temperature relationship data is the relationship data between the time step parameter and the temperature parameter; based on the first time step parameter, through the well temperature relationship data, determine the temperature parameter of the well section in the time step; based on the temperature parameter of each well section at each time step, determine the temperature parameter of the target wellbore. This method improves the accuracy of the determined wellbore temperature parameters.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas field development engineering, and in particular to a method, device and computer equipment for determining wellbore temperature parameters. Background Art

[0002] The pressure in a gas well is an important parameter for gas well production process design and production dynamic analysis. In the actual development of oil and gas fields, due to various reasons such as process, safety and cost, some gas wells cannot install pressure gauges in the wellbore and cannot measure the wellbore pressure. There is a preset conversion relationship between the wellbore pressure and temperature; therefore, the wellbore pressure can be obtained by obtaining the wellbore temperature and converting the temperature.

[0003] In the related art, it is generally assumed that the gas well production is stable and the wellbore temperature is linearly distributed in the vertical direction. The temperature at the wellbore depth to be measured is determined by using the wellhead temperature and the distance between the wellbore depth to be measured and the wellhead. Since the gas well production changes all the time during the gas well exploitation process, the change in gas well production affects the wellbore temperature. Therefore, the wellbore temperature determined by this method has low accuracy. Summary of the invention

[0004] The embodiments of the present application provide a method, device and computer equipment for determining the wellbore temperature, which can improve the accuracy of the determined wellbore temperature. The technical solution is as follows:

[0005] In one aspect, a method for determining a wellbore temperature parameter is provided, the method comprising:

[0006] Determine a plurality of well sections of a target wellbore to be studied, wherein the plurality of well sections are well sections divided sequentially from the bottom to the wellhead of the target wellbore;

[0007] Determine a plurality of time steps of the target wellbore, wherein the plurality of time steps are time periods obtained by sequentially dividing the production time of the target wellbore;

[0008] For each time step of each well section, obtaining a first time step parameter of the well section at the time step;

[0009] Acquire well temperature relationship data of a target well area where the target wellbore is located, wherein the well temperature relationship data is relationship data between a time step parameter and a temperature parameter;

[0010] Based on the first time step parameter, determine the temperature parameter of the well section at the time step through the well temperature relationship data;

[0011] The temperature parameter of the target wellbore is determined based on the temperature parameter of each well section at each time step.

[0012] In a possible implementation, the step of obtaining the well temperature relationship data of the target well area where the target wellbore is located includes:

[0013] Acquire first equilibrium relationship data, second equilibrium relationship data, and third equilibrium relationship data of the target well area, wherein the first equilibrium relationship data is the relationship data between temperature, time, and heat flow rate when the fluid heat transfer between the formation and the well wall of the target well area is in equilibrium, the second relationship data is the relationship data between temperature and heat flow rate when the fluid heat transfer between the well wall and the target wellbore is in equilibrium, and the third relationship data is the relationship data between pressure gradient and heat flow rate when the fluid convection heat transfer of the formation is in equilibrium;

[0014] Convolving the first equilibrium relationship data to obtain convolution relationship data, wherein the convolution relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when heat transfer equilibrium is achieved between the formation and the well wall;

[0015] Determine the sum of the second equilibrium relationship data and the convolution relationship data to obtain fourth equilibrium relationship data, wherein the fourth equilibrium relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when the fluid heat transfer between the formation and the target wellbore is in equilibrium;

[0016] The well temperature relationship data is determined based on the third balance relationship data and the fourth balance relationship data.

[0017] In a possible implementation, the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0018] The determining the well temperature relationship data based on the third balance relationship data and the fourth balance relationship data comprises:

[0019] Splitting the fourth equilibrium relationship data into the heat flux relationship data, the instantaneous heat transfer relationship data and the apparent heat flux relationship data, the heat flux relationship data is used to represent the relationship data relationship between the heat flux, the instantaneous heat transfer coefficient and the apparent heat flux of the target wellbore, the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient and the time step of the target wellbore, the apparent heat flux relationship data is used to represent the relationship data relationship between the apparent heat flux, the heat flux and the time step of the target wellbore, and the fluid temperature function is used to represent the relationship data relationship between the fluid temperature, the instantaneous heat transfer coefficient, the apparent heat flux and the pressure gradient of the target wellbore;

[0020] The third equilibrium relationship data and the heat flow rate relationship data are synthesized to obtain the fluid temperature relationship data.

[0021] In a possible implementation, the first time step parameter includes the pressure gradient of the time step, and the time step is not the first time step, then obtaining the first time step parameter of the well section at the time step includes:

[0022] Acquire the first fluid temperature of the well section at the previous time step and the second fluid temperature of the previous well section at the current time step;

[0023] determining a first wellbore pressure matching the first fluid temperature and a second wellbore pressure matching the second fluid temperature based on the first fluid temperature and the second fluid temperature, respectively;

[0024] The pressure gradient is determined based on a depth difference between the well section and the previous well section, the first wellbore pressure, and the second wellbore pressure.

[0025] In a possible implementation, the first time step parameter includes an initial pressure gradient, the time step is the first time step, and the well section is the first well section, then obtaining the first time step parameter of the well section in the time step includes:

[0026] Obtaining an initial fluid temperature at the bottom of the wellbore and a preset wellbore pressure of the first well section;

[0027] Based on the initial fluid temperature, determining an initial wellbore pressure matching the initial fluid temperature;

[0028] The initial pressure gradient is determined based on the depth difference between the first well section and the bottom of the wellbore, the initial wellbore pressure and the preset wellbore pressure.

[0029] In a possible implementation, the method further includes:

[0030] For each time step, when the well section is the last well section, obtaining the wellhead pressure and final fluid temperature of the target wellbore at the time step, wherein the final fluid temperature is the fluid temperature of the last well section at the time step;

[0031] Based on the final fluid temperature, determining a final wellbore pressure matching the final fluid temperature;

[0032] The preset wellbore pressure is adjusted based on the difference between the final wellbore pressure and the wellhead pressure.

[0033] In a possible implementation, the temperature parameter of the well section at the time step includes a first fluid temperature and a first heat flow rate, and the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0034] The first time step parameters include the pressure gradient at the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. If the time step is not the first time step, then the temperature parameters of the well section at the time step are determined based on the first time step parameters and through the well temperature relationship data, including:

[0035] Based on the time step time of the time step, determining a first instantaneous heat transfer coefficient at the time step through the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time;

[0036] Based on each heat flow rate from the first time step to the previous time step and each time step time from the first time step to the time step, determining the first apparent heat flow rate at the time step through the apparent heat flow rate relationship data, the apparent heat flow rate relationship data being used to represent the relationship data relationship between the apparent heat flow rate, heat flow rate, and time step time of the target wellbore;

[0037] Based on the boundary condition parameters, the first apparent heat flow rate and the pressure gradient, the first fluid temperature at the time step is determined through the fluid temperature relationship data, and the fluid temperature function is used to represent the relationship data between the fluid temperature, the instantaneous heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore;

[0038] Based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature, the first heat flow rate at the time step is determined through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore.

[0039] In a possible implementation, the temperature parameter of the well section at the time step includes a second fluid temperature and a second heat flow rate, and the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0040] The first time step parameters include the initial pressure gradient, initial time step time, initial heat flow rate, boundary condition parameters of the target wellbore and formation temperature corresponding to the well section at the time step, the time step is the first time step, and the well section is the first well section, then based on the first time step parameters, determining the temperature parameters of the well section at the time step through the well temperature relationship data includes:

[0041] Based on the initial time step, determining a second instantaneous heat transfer coefficient at the first time step by using the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time;

[0042] Based on the initial heat flow rate, determining a second apparent heat flow rate at the first time step through the apparent heat flow rate relationship data, the apparent heat flow rate relationship data being used to represent the relationship data relationship between the apparent heat flow rate, heat flow rate, and time step time of the target wellbore;

[0043] Based on the boundary condition parameters, the second apparent heat flow rate and the initial pressure gradient, the second fluid temperature at the first time step is determined through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore;

[0044] Based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature, the second heat flow rate at the first time step is determined through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, instantaneous heat transfer coefficient and apparent heat flow rate of the target wellbore.

[0045] In another aspect, a device for determining a wellbore temperature parameter is provided, the device comprising:

[0046] A first determination module is used to determine a plurality of well sections of a target wellbore to be studied, wherein the plurality of well sections are well sections divided sequentially from the bottom to the wellhead of the target wellbore;

[0047] A second determination module is used to determine a plurality of time steps of the target wellbore, wherein the plurality of time steps are time periods obtained by sequentially dividing the production time of the target wellbore;

[0048] A first acquisition module is used to acquire, for each time step of each well section, a first time step parameter of the well section at the time step;

[0049] A second acquisition module is used to acquire well temperature relationship data of a target well area where the target wellbore is located, wherein the well temperature relationship data is relationship data between a time step parameter and a temperature parameter;

[0050] A third determination module is used to determine the temperature parameter of the well section at the time step based on the first time step parameter and through the well temperature relationship data;

[0051] The fourth determination module is used to determine the temperature parameter of the target wellbore based on the temperature parameter of each well section at each time step.

[0052] In a possible implementation, the second acquisition module includes:

[0053] A first acquisition unit is used to acquire first equilibrium relationship data, second equilibrium relationship data and third equilibrium relationship data of the target well area, wherein the first equilibrium relationship data is the relationship data between temperature, time and heat flow rate when the fluid heat transfer between the formation and the well wall of the target well area is in equilibrium, the second relationship data is the relationship data between temperature and heat flow rate when the fluid heat transfer between the well wall and the target wellbore is in equilibrium, and the third relationship data is the relationship data between pressure gradient and heat flow rate when the fluid convection heat transfer of the formation is in equilibrium;

[0054] A convolution unit, configured to convolve the first equilibrium relationship data to obtain convolution relationship data, wherein the convolution relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when heat transfer between the formation and the well wall is in equilibrium;

[0055] a first determining unit, configured to determine the sum of the second equilibrium relationship data and the convolution relationship data to obtain fourth equilibrium relationship data, wherein the fourth equilibrium relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when the fluid heat transfer between the formation and the target wellbore is in equilibrium;

[0056] The second determining unit is used to determine the well temperature relationship data based on the third balance relationship data and the fourth balance relationship data.

[0057] In a possible implementation, the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0058] The second determining unit includes:

[0059] a splitting unit, for splitting the fourth equilibrium relationship data into the heat flow rate relationship data, the instantaneous heat transfer relationship data and the apparent heat flow rate relationship data, the heat flow rate relationship data being used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore, the instantaneous heat transfer relationship data being used to represent the relationship data relationship between the instantaneous heat transfer coefficient and the time step time of the target wellbore, and the apparent heat flow rate relationship data being used to represent the relationship data relationship between the apparent heat flow rate, the heat flow rate and the time step time of the target wellbore;

[0060] A synthesis unit is used to synthesize the third equilibrium relationship data and the heat flow rate relationship data to obtain the fluid temperature relationship data.

[0061] In a possible implementation, the first time step parameter includes a pressure gradient of the time step, and the time step is not the first time step, then the first acquisition module includes:

[0062] A second acquisition unit is used to acquire the first fluid temperature of the well section at the previous time step and the second fluid temperature of the previous well section at the current time step;

[0063] a third determining unit, configured to determine a first wellbore pressure matching the first fluid temperature and a second wellbore pressure matching the second fluid temperature based on the first fluid temperature and the second fluid temperature, respectively;

[0064] The fourth determination unit is used to determine the pressure gradient based on the depth difference between the well section and the previous well section, the first wellbore pressure and the second wellbore pressure.

[0065] In a possible implementation, the first time step parameter includes an initial pressure gradient, the time step is the first time step, and the well section is the first well section, then the first acquisition module includes:

[0066] A third acquisition unit, used to acquire the initial fluid temperature at the bottom of the wellbore and the preset wellbore pressure of the first well section;

[0067] a fifth determining unit, configured to determine, based on the initial fluid temperature, an initial wellbore pressure matching the initial fluid temperature;

[0068] A sixth determination unit is used to determine the initial pressure gradient based on the depth difference between the first well section and the bottom of the wellbore, the initial wellbore pressure and the preset wellbore pressure.

[0069] In a possible implementation manner, the device further includes:

[0070] A third acquisition module is used for acquiring, for each time step, the wellbore wellhead pressure and final fluid temperature at the time step when the well section is the last well section, wherein the final fluid temperature is the fluid temperature of the last well section at the time step;

[0071] a fifth determination module, configured to determine, based on the final fluid temperature, a final wellbore pressure matching the final fluid temperature;

[0072] An adjustment module is used to adjust the preset wellbore pressure based on the difference between the final wellbore pressure and the wellhead pressure.

[0073] In a possible implementation, the temperature parameter of the well section at the time step includes a first fluid temperature and a first heat flow rate, and the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0074] The first time step parameters include the pressure gradient of the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. If the time step is not the first time step, the third determination module includes:

[0075] a seventh determining unit, for determining a first instantaneous heat transfer coefficient at the time step based on the time step time of the time step by means of the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent a relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time;

[0076] an eighth determination unit, configured to determine a first apparent heat flow rate at the time step based on each heat flow rate from the first time step to the previous time step and each time step time from the first time step to the time step through the apparent heat flow rate relationship data, wherein the apparent heat flow rate relationship data is used to represent a relationship data relationship between an apparent heat flow rate, a heat flow rate, and a time step time of the target wellbore;

[0077] a ninth determining unit, configured to determine the first fluid temperature at the time step based on the boundary condition parameter, the first apparent heat flow rate and the pressure gradient through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore;

[0078] A tenth determination unit is used to determine the first heat flow rate at the time step based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore.

[0079] In a possible implementation, the temperature parameter of the well section at the time step includes a second fluid temperature and a second heat flow rate, and the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0080] The first time step parameters include the initial pressure gradient of the time step, the initial time step time, the initial heat flow rate, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section, the time step is the first time step, and the well section is the first well section, then the third determination module includes:

[0081] an eleventh determining unit, for determining a second instantaneous heat transfer coefficient at the first time step based on the initial time step by means of the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent a relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time;

[0082] a twelfth determining unit, for determining a second apparent heat flow rate at the first time step based on the initial heat flow rate and through the apparent heat flow rate relationship data, wherein the apparent heat flow rate relationship data is used to represent a relationship data relationship between the apparent heat flow rate, the heat flow rate, and the time step time of the target wellbore;

[0083] a thirteenth determining unit, for determining the second fluid temperature at the first time step based on the boundary condition parameter, the second apparent heat flow rate and the initial pressure gradient through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore;

[0084] A fourteenth determination unit is used to determine the second heat flow rate at the first time step based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore.

[0085] On the other hand, a computer device is provided, which includes one or more processors and one or more memories, wherein at least one instruction is stored in the one or more memories, and the at least one instruction is loaded and executed by the one or more processors to implement the operations performed by the wellbore temperature parameter determination method as described above.

[0086] On the other hand, a computer-readable storage medium is provided, in which at least one program code is stored, and the at least one program code is loaded and executed by a processor to implement the steps in the method for determining the wellbore temperature parameters described in any of the above implementations.

[0087] On the other hand, a computer program product or a computer program is provided, the computer program product or the computer program comprising a computer program code, the computer program code being stored in a computer-readable storage medium. A processor of a computer device reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code, so that the computer device performs the operations performed by the above-mentioned wellbore temperature parameter determination method.

[0088] The beneficial effects of the technical solution provided by the embodiments of the present application include at least:

[0089] An embodiment of the present application provides a method for determining wellbore temperature parameters. Since the method divides the target wellbore into multiple well sections and multiple time steps, the temperature parameters of each well section at each time step can be determined through well temperature relationship data, thereby achieving accurate division of the temperature parameters of the target wellbore. In this way, the temperature parameters of each well section at each time step can be regarded as instantaneously stable temperature parameters, so that the temperature parameters match the actual well conditions of each well section at each time step, thereby improving the accuracy of the determined wellbore temperature parameters. BRIEF DESCRIPTION OF THE DRAWINGS

[0090] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0091] Figure 1 is a flow chart of a method for determining wellbore temperature parameters provided in an embodiment of the present application;

[0092] Figure 2 is a schematic diagram of multiple well sections of a wellbore provided in an embodiment of the present application;

[0093] Figure 3 is a schematic diagram of a wellbore provided in an embodiment of the present application;

[0094] Figure 4 It is a temperature comparison diagram of a wellbore provided in an embodiment of the present application;

[0095] Figure 5 is a flow chart of a method for determining wellbore temperature parameters provided in an embodiment of the present application;

[0096] Figure 6 is a block diagram of a wellbore temperature parameter determination device provided in an embodiment of the present application;

[0097] Figure 7 It is a block diagram of a computer device provided in an embodiment of the present application. DETAILED DESCRIPTION

[0098] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below with reference to the accompanying drawings.

[0099] The terms "first", "second", "third" and "fourth" etc. in the specification and claims of the present application and the drawings are used to distinguish different objects, rather than to describe a specific order. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions. For example, a process, method, system, product or device that includes a series of steps or units is not limited to the listed steps or units, but optionally includes steps or units that are not listed, or optionally includes other steps or units inherent to these processes, methods, products or devices.

[0100] The present application embodiment provides a method for determining a wellbore temperature parameter. Figure 1 , methods include:

[0101] Step 101: A computer device determines a plurality of well sections of a target wellbore to be studied.

[0102] The target wellbore to be studied may be a wellbore of a gas well with a large pressure difference and a low productivity.

[0103] Among them, the multiple well sections are well sections divided in sequence from the bottom of the wellbore to the wellhead.

[0104] The computer device divides the wellbore into sections based on at least one of the wellbore's inclination depth, vertical depth, tubing inner diameter, tubing roughness, well inclination angle and other parameters; for example, wellbore areas with the same inclination depth are divided into the same wellbore section; for another example, wellbore areas with the same tubing inner diameter are divided into the same wellbore section; for another example, wellbore areas with the same inclination depth, vertical depth, tubing inner diameter, tubing roughness, well inclination angle and other parameters are divided into the same wellbore section.

[0105] For example, see Table 1, which shows the vertical depths and well inclination angles of multiple same depth measurement positions of a target wellbore. The wellbore areas with the same vertical depth and well inclination angle are divided into the same well section. The multiple well sections obtained by the division are shown in Table 1. Figure 2 , and number multiple well sections from the bottom of the well to the wellhead as 1, 2, 3, …, n.

[0106] Table 1

[0107] Step 102: The computer device determines a plurality of time steps of the target wellbore.

[0108] The multiple time steps are time periods obtained by sequentially dividing the production time of the target wellbore. The number of the multiple time steps is m, and the multiple time steps are sequentially numbered as 1, 2, 3, ..., m.

[0109] Step 103: For each time step of each well section, the computer obtains the first time step parameter of the well section at the time step.

[0110] In a possible implementation, the first time step parameter includes an initial pressure gradient; if the time step is the first time step and the well section is the first well section, step 103 can be implemented by the following steps (1)-(3):

[0111] (1) The computer equipment obtains the initial fluid temperature at the bottom of the wellbore and the preset wellbore pressure of the first well section.

[0112] The initial fluid temperature at the bottom of the wellbore is measured by a temperature measuring device at the bottom of the wellbore, and the preset wellbore pressure is preset based on the historical wellbore pressure of the target wellbore.

[0113] (2) The computer device determines an initial wellbore pressure that matches the initial fluid temperature based on the initial fluid temperature.

[0114] Wherein, the computer device determines the high-pressure physical property parameters of the fluid in the wellbore that match the initial fluid temperature based on the initial fluid temperature; and determines the initial wellbore pressure that matches the high-pressure physical property parameters based on the high-pressure physical property parameters.

[0115] In one possible implementation, a computer device stores a correspondence between an initial fluid temperature and high-pressure physical property parameters; accordingly, the step in which the computer device determines, based on the initial fluid temperature, the high-pressure physical property parameters of the fluid in the wellbore that match the initial fluid temperature includes: the computer device determines, based on the initial fluid temperature, the high-pressure physical property parameters corresponding to the initial fluid temperature from the correspondence between the initial fluid temperature and the high-pressure physical property parameters.

[0116] In another possible implementation, a computer device may determine high-pressure physical property parameters with the aid of a parameter determination model based on neural network training; the parameter determination model is used to determine the high-pressure physical property parameters based on the initial fluid temperature; accordingly, the step in which the computer device determines the high-pressure physical property parameters of the fluid in the wellbore that matches the initial fluid temperature based on the initial fluid temperature includes: the computer device inputs the initial fluid temperature into the parameter determination model and outputs the high-pressure physical property parameters.

[0117] Among them, the high-pressure physical property parameters include fluid density, volume coefficient, compressibility coefficient, etc. When the computer device determines the initial wellbore pressure based on the high-pressure physical property parameters, it can also use the wellbore flow pressure calculation model based on neural network training to determine; the wellbore flow pressure calculation model is used to determine the initial wellbore pressure based on the high-pressure physical property parameters; accordingly, the step of the computer device determining the initial wellbore pressure matching the high-pressure physical property parameters based on the high-pressure physical property parameters includes: the computer device inputs the high-pressure physical property parameters into the wellbore flow pressure calculation model and outputs the initial wellbore pressure.

[0118] Among them, the wellbore flow pressure calculation models include the Beggs-Brill method published in 1974, the Orkiswski method (a wellbore flow pressure calculation method) published in 1967, the Hagedorn-Brown method published in 1963 and 1965, the Chierice method published in 1974, the Hasan method and the Kabir method published in 1988, etc.

[0119] Among them, the wellbore flow pressure calculation model includes multiple calculation methods. In the embodiment of the present application, at least one method among the multiple calculation methods is used to determine the initial wellbore pressure matching the high-pressure physical property parameters.

[0120] (3) The computer device determines an initial pressure gradient based on the depth difference between the first well section and the bottom of the wellbore, the initial wellbore pressure, and the preset wellbore pressure.

[0121] Among them, the depth difference between the first well section and the bottom of the wellbore can be directly obtained from the logging data of the target wellbore.

[0122] The computer device determines the pressure difference between the preset wellbore pressure and the initial wellbore pressure, and then determines the quotient of the pressure difference and the depth difference to obtain the initial pressure gradient.

[0123] In another possible implementation, the first time step parameter includes the pressure gradient of the time step, and the time step is not the first time step, that is, when m is greater than 1, step 103 can be implemented by the following steps (A)-(C):

[0124] (A) The computer device obtains the first fluid temperature of the well section at the previous time step and the second fluid temperature of the previous well section at the current time step.

[0125] Wherein, when the well section is the first well section, the second fluid temperature is the initial fluid temperature.

[0126] Among them, the first fluid temperature of the well section in the previous time step and the second fluid temperature of the previous well section in this time step can be obtained from the temperature parameters of the well section in the previous time step and the temperature parameters of the previous well section in this time step respectively, and the temperature parameters include fluid temperature and heat flow rate.

[0127] (B) The computer device determines a first wellbore pressure matching the first fluid temperature and a second wellbore pressure matching the second fluid temperature based on the first fluid temperature and the second fluid temperature, respectively.

[0128] The computer device determines the high-pressure physical property parameters of the fluid in the wellbore that match the first fluid temperature based on the first fluid temperature; and determines the first wellbore pressure that matches the high-pressure physical property parameters based on the high-pressure physical property parameters.

[0129] In one possible implementation, a computer device stores a correspondence between a first fluid temperature and high-pressure physical property parameters; accordingly, the step in which the computer device determines, based on the first fluid temperature, the high-pressure physical property parameters of the fluid in the wellbore that matches the first fluid temperature includes: the computer device determines, based on the first fluid temperature, the high-pressure physical property parameters corresponding to the first fluid temperature from the correspondence between the first fluid temperature and the high-pressure physical property parameters.

[0130] In another possible implementation, a computer device may determine high-pressure physical property parameters with the aid of a parameter determination model based on neural network training; the parameter determination model is used to determine the high-pressure physical property parameters based on a first fluid temperature; accordingly, the step in which the computer device determines the high-pressure physical property parameters of the fluid in the wellbore that matches the first fluid temperature based on the first fluid temperature includes: the computer device inputs the first fluid temperature into the parameter determination model and outputs the high-pressure physical property parameters.

[0131] Wherein, the high-pressure physical property parameters include fluid density, volume coefficient, compressibility coefficient, etc. When the computer device determines the first wellbore pressure based on the high-pressure physical property parameters, it can also use the wellbore flow pressure calculation model based on neural network training to determine; the wellbore flow pressure calculation model is used to determine the first wellbore pressure based on the high-pressure physical property parameters; accordingly, the step of the computer device determining the first wellbore pressure matching the high-pressure physical property parameters based on the high-pressure physical property parameters includes: the computer device inputs the high-pressure physical property parameters into the wellbore flow pressure calculation model, and outputs the first wellbore pressure.

[0132] The computer device determines the high-pressure physical property parameters of the fluid in the wellbore that match the second fluid temperature based on the second fluid temperature; and determines the second wellbore pressure that matches the high-pressure physical property parameters based on the high-pressure physical property parameters.

[0133] In one possible implementation, a computer device stores a correspondence between a second fluid temperature and high-pressure physical property parameters; accordingly, the step in which the computer device determines, based on the second fluid temperature, the high-pressure physical property parameters of the fluid in the wellbore that matches the second fluid temperature includes: the computer device determines, based on the second fluid temperature, the high-pressure physical property parameters corresponding to the second fluid temperature from the correspondence between the second fluid temperature and the high-pressure physical property parameters.

[0134] In another possible implementation, the computer device can determine the high-pressure physical property parameters with the help of a parameter determination model based on neural network training; the parameter determination model is used to determine the high-pressure physical property parameters based on the second fluid temperature; accordingly, the computer device determines the high-pressure physical property parameters of the fluid in the wellbore that matches the second fluid temperature based on the second fluid temperature, including: the computer device inputs the second fluid temperature into the parameter determination model and outputs the high-pressure physical property parameters.

[0135] Wherein, the high-pressure physical property parameters include fluid density, volume coefficient, compressibility coefficient, etc. When the computer device determines the second wellbore pressure based on the high-pressure physical property parameters, it can also use the wellbore flow pressure calculation model based on neural network training to determine; the wellbore flow pressure calculation model is used to determine the second wellbore pressure based on the high-pressure physical property parameters; accordingly, the step of the computer device determining the second wellbore pressure matching the high-pressure physical property parameters based on the high-pressure physical property parameters includes: the computer device inputs the high-pressure physical property parameters into the wellbore flow pressure calculation model, and outputs the second wellbore pressure.

[0136] (C) The computer device determines the pressure gradient based on the depth difference between the well section and the previous well section, the first wellbore pressure and the second wellbore pressure.

[0137] Among them, the depth difference between this well section and the previous well section can be directly obtained from the logging data.

[0138] The computer device determines the pressure difference between the second wellbore pressure and the first wellbore pressure, and then determines the quotient of the pressure difference and the depth difference to obtain a first pressure gradient.

[0139] Step 104: The computer device obtains the well temperature relationship data of the target well area where the target wellbore is located.

[0140] Among them, the well temperature relationship data is the relationship data between the time step parameter and the temperature parameter.

[0141] This step can be achieved by following the steps (1)-(4):

[0142] (1) The computer device obtains the first balance relationship data, the second balance relationship data and the third balance relationship data of the target well area.

[0143] Among them, the first equilibrium relationship data is the relationship data between temperature, time and heat flow rate when the fluid heat transfer between the formation and the wellbore in the target well area is in equilibrium; the second relationship data is the relationship data between temperature and heat flow rate when the fluid heat transfer between the wellbore and the target wellbore is in equilibrium; the third relationship data is the relationship data between pressure gradient and heat flow rate when the fluid convection heat transfer in the formation is in equilibrium.

[0144] The first balance relationship data, the second balance relationship data and the third balance relationship data can all be obtained from the well logging data of the target well area.

[0145] The first equilibrium relationship data is:

[0146] The second equilibrium relationship data is:

[0147] The third balance relationship data is:

[0148] Among them, T ei is the formation temperature, in °C, T wb is the well wall temperature, in °C; Q is the heat flow rate, in W / m; K e is the formation thermal conductivity, unit is W / (mK); T D (t D ) is the dimensionless temperature distribution relationship data, dimensionless; t D is the dimensionless heat conduction time, dimensionless; T f is the fluid temperature, in °C; r t0 is the outer radius of the oil pipe, in m; U t0 is the total heat transfer coefficient, in W / (m 2 .K); w is the fluid mass flow rate, in kg / s; H is the fluid specific enthalpy, in J / kg; v is the fluid flow velocity, in m / s; g is the gravitational acceleration, 9.8m / s; z is the depth of the well section, in m; θ is the horizontal angle of the wellbore, in degrees.

[0149] Among them, parameters such as formation thermal conductivity, tubing outer radius, total heat transfer coefficient, fluid mass flow rate, fluid flow velocity, well section depth and wellbore horizontal angle can be directly obtained from logging data; for example, see Table 2, which is a parameter value table of a target well.

[0150] Table 2

[0151]

[0152]

[0153] Among them, T D (t D ) is the dimensionless temperature distribution relationship data, and its approximate solution is:

[0154]

[0155] Among them, T D is the dimensionless temperature, defined as t Dis the dimensionless heat conduction time, defined as:

[0156] Among them, ρ e is the rock density of the formation, in kg / m, C e is the specific heat of formation rock, in J / (kg.K); r w is the radius of the open hole wellbore, in meters; t is the heat transfer time, in seconds; the formation rock density, formation rock specific heat and the radius of the open hole wellbore can be directly obtained from the logging data of the target wellbore.

[0157] (2) The computer device convolves the first balance relationship data to obtain convolution relationship data.

[0158] The convolution relationship data are the relationship data between the temperature, each time step time, and the heat flow rate corresponding to each time step time when the heat transfer between the formation and the well wall is in equilibrium.

[0159] The computer device integrates the first equilibrium relationship data to obtain heat flow rate superposition relationship data, and the computer device divides the time of the heat flow rate superposition relationship data into time steps to obtain convolution relationship data.

[0160] Among them, the heat flow rate superposition relationship data is the relationship data between the temperature, each time, and the heat flow rate corresponding to each time when the heat transfer between the formation and the well wall of the target well area is in equilibrium. The heat flow rate superposition relationship data is obtained by superimposing the heat flow rate at each time in the production time period of the target wellbore to obtain the target heat flow rate in the production time period, and then the temperature is obtained based on the target heat flow rate.

[0161] Among them, the heat flow rate superposition relationship data is:

[0162] Where Q′(τ) is the time derivative of the heat flow rate at the time point τ.

[0163] The computer device divides the production time period into multiple time steps by dividing the production time period, and the number of the multiple time steps is m.

[0164] Among them, the convolution relationship data is:

[0165] Among them, the heat flow rate at each time step can be expressed as Q0, Q1, Q2...Q m ;t i is the time step time of the ith time step, is the time when the ith time step starts, Among them, t1=0, Q0=0.

[0166] In an embodiment of the present application, the overall heat flow rate of the production time period is divided into multiple heat flow rates in multiple time steps, and then the heat flow rate of each time step can be used as the instantaneous stable heat flow rate, and the temperature is determined based on the superposition of multiple instantaneous stable heat flow rates, thereby achieving accurate division of temperature and heat flow rate in each time step.

[0167] (3) The computer device determines the sum of the second balance relationship data and the convolution relationship data to obtain fourth balance relationship data.

[0168] The fourth equilibrium relationship data is the relationship data between the temperature, each time step time, and the heat flow rate corresponding to each time step time when the fluid heat transfer between the formation and the target wellbore is in equilibrium.

[0169] The computer device respectively adds the formulas on both sides of the equal sign of the second balance relationship data and the convolution relationship data to obtain the fourth balance relationship data.

[0170] Among them, the second balance relationship data is:

[0171] The convolution relationship data is:

[0172] The fourth equilibrium relationship data is:

[0173]

[0174] Among them, T f (t i ) is the fluid temperature at the i-th time step.

[0175] (4) The computer device determines the well temperature relationship data based on the third balance relationship data and the fourth balance relationship data.

[0176] Among them, the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data.

[0177] This step can be achieved by following the steps A1-A2:

[0178] A1: The computer device splits the fourth equilibrium relationship data into heat flow rate relationship data, instantaneous heat transfer relationship data and apparent heat flow rate relationship data.

[0179] Among them, the heat flux relationship data is used to represent the relationship data between the heat flux, instantaneous heat transfer coefficient, and apparent heat flux of the target wellbore; the instantaneous heat transfer relationship data is used to represent the relationship data between the instantaneous heat transfer coefficient and the step time of the target wellbore; the apparent heat flux relationship data is used to represent the relationship data between the apparent heat flux, heat flux, and step time of the target wellbore; the fluid temperature function is used to represent the relationship data between the fluid temperature, instantaneous heat transfer coefficient, apparent heat flux, and pressure gradient of the target wellbore.

[0180] Among them, the fourth balance relationship data is:

[0181]

[0182] The heat flow rate relationship data is: Q m =L R [T ei -T f (t i )]+ω.

[0183] The transient heat transfer relationship data is:

[0184] The heat flow rate relationship data is:

[0185]

[0186] Among them, Q m is the heat flow rate at the mth time step, in W / m, L R is the instantaneous heat transfer coefficient, dimensionless, and ω is the apparent heat flux, in W / m.

[0187] A2: The computer device synthesizes the third equilibrium relationship data and the heat flow rate relationship data to obtain fluid temperature relationship data.

[0188] Among them, the third balance relationship data is:

[0189] The heat flow rate relationship data is: Q m =L R [T ei -T f (t i )]+ω.

[0190] Among them, H is the specific enthalpy of the fluid, and its specific enthalpy relationship data is:

[0191] The computer device substitutes the specific enthalpy relationship data and the heat flow rate relationship data into the third equilibrium relationship data to obtain the fluid temperature expansion relationship data.

[0192] The fluid temperature expansion relationship data is:

[0193]

[0194] Among them, C J is the Joule-Thompson coefficient of the fluid, in K / Pa; c p is the specific heat of the fluid, in J / (kg.K); is the pressure gradient, in MPa / m; the Joule-Thompson coefficient and fluid specific heat can be directly obtained from the logging data of the target wellbore.

[0195] The computer device simplifies the fluid temperature expansion relationship data to obtain the fluid temperature simplified relationship data.

[0196] The simplified relationship data of fluid temperature is:

[0197]

[0198] in, L, L Rm and ω m These are simplification factors.

[0199] The computer device obtains the boundary condition relationship data of the wellbore, synthesizes the boundary condition relationship data with the simplified relationship data of the fluid temperature, and obtains the fluid temperature relationship data.

[0200] Among them, the boundary condition relationship data is: T ei =T ei0 +g G z.

[0201] T ei0 is the initial formation temperature at the bottom of the well, in °C; g G is the geothermal gradient, in units of ℃ / m; z is the depth of the well section, in units of m; the initial formation temperature, geothermal gradient and depth of the well section can be directly obtained from the logging data of the target wellbore.

[0202] The fluid temperature relationship data is:

[0203]

[0204] in,

[0205] Among them, T ei0 is the initial formation temperature at the bottom of the well, in °C; T f0 is the initial fluid temperature at the bottom of the well, in °C.

[0206] Step 105: The computer device determines the temperature parameter of the well section at the time step based on the first time step parameter and the well temperature relationship data.

[0207] In a possible implementation, the first time step parameters include the pressure gradient of the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. The time step is not the first time step. This step can be implemented by the following steps (1)-(4):

[0208] (1) The computer device determines the first instantaneous heat transfer coefficient at the time step based on the time step time of the time step and through the instantaneous heat transfer relationship data.

[0209] Among them, the transient heat transfer relationship data is:

[0210] The computer device substitutes the time step into the instantaneous heat transfer relationship data to obtain the first instantaneous heat transfer coefficient at the time step.

[0211] (2) The computer device determines the first apparent heat flow rate at the time step based on each heat flow rate from the first time step to the previous time step and each time step from the first time step to the current time step through the apparent heat flow rate relationship data.

[0212] Among them, each time step time is the time point at which each time step starts, each heat flow rate from the first time step to the previous time step can be obtained from the temperature parameters of the well section from the first time step to the previous time step, and the formation temperature corresponding to the well section can be obtained from the logging data of the target wellbore.

[0213] The heat flow rate relationship data is:

[0214]

[0215] The computer device substitutes each heat flow rate from the first time step to the previous time step and each time step time from the first time step to the current time step into the apparent heat flow rate relationship data to obtain the first apparent heat flow rate at the current time step.

[0216] (3) The computer device determines the first fluid temperature at the time step based on the boundary condition parameters, the first apparent heat flow rate and the pressure gradient and the fluid temperature relationship data.

[0217] The boundary condition parameters of the wellbore include the initial formation temperature T at the bottom of the well. ei0 , the initial fluid temperature at the bottom of the well is T f0 , can be obtained from the logging data of the target wellbore; see Figure 3 , the initial formation temperature and the initial fluid temperature are the formation temperature and the fluid temperature corresponding to the wellbore entrance respectively, and L in the figure is the overall length of the wellbore.

[0218] Among them, the fluid temperature relationship data is:

[0219]

[0220] in,

[0221] The computer device substitutes the boundary condition parameters, the first apparent heat flow rate and the first pressure gradient into the fluid temperature relationship data to obtain the first fluid temperature at the time step.

[0222] See also Figure 4 By comparing the first fluid temperature of the last well section with the actually measured wellhead temperature, it can be seen that the first fluid temperature determined by the method provided in the embodiment of the present application is basically consistent with the wellhead temperature, indicating that the accuracy of the wellbore temperature determined by the embodiment of the present application is high.

[0223] (4) The computer device determines the first heat flow rate at the time step based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature through the heat flow rate relationship data.

[0224] Among them, the heat flow rate relationship data is: Q m =L R [T ei -T f (t i )]+ω.

[0225] The computer device substitutes the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature into the heat flow rate relationship data to obtain the first heat flow rate at the time step.

[0226] In another possible implementation, the first time step parameters include the initial pressure gradient of the time step, the initial time step time, the initial heat flow rate, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section, the time step is the first time step, and the well section is the first well section, then step 105 can be implemented by the following steps (A)-(D):

[0227] (A) The computer device determines the second instantaneous heat transfer coefficient at the first time step based on the initial time step time and the instantaneous heat transfer relationship data.

[0228] Among them, the transient heat transfer relationship data is:

[0229] The computer device substitutes the initial time step into the instantaneous heat transfer relationship data to obtain the second instantaneous heat transfer coefficient at the first time step.

[0230] (B) The computer device determines the second apparent heat flow rate at the first time step based on the initial heat flow rate using the apparent heat flow rate relationship data.

[0231] Among them, the initial heat flow rate Q0=0, and the initial heat flow rate is substituted into the apparent heat flow rate relationship data to obtain the second apparent heat flow rate ω=0 in the first time step.

[0232] (C) The computer device determines the second fluid temperature at the first time step based on the boundary condition parameters, the second apparent heat flow rate and the initial pressure gradient through the fluid temperature relationship data.

[0233] Among them, the fluid temperature relationship data is:

[0234]

[0235] in,

[0236] The computer device substitutes the boundary condition parameters, the second apparent heat flow rate and the initial pressure gradient into the fluid temperature relationship data to obtain the second fluid temperature at the first time step.

[0237] (D) The computer device determines the second heat flow rate at the first time step based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature using the heat flow rate relationship data.

[0238] Among them, the heat flow rate relationship data is: Q m =L R [T ei -T f (t i )]+ω.

[0239] The computer device substitutes the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature into the heat flow rate relationship data to obtain the second heat flow rate at the first time step.

[0240] Step 106: The computer device determines the temperature parameters of the target wellbore based on the temperature parameters of each well section at each time step.

[0241] The temperature parameters of the target wellbore include the temperature parameters of each well section at each time step, and the computer device combines the temperature parameters of each well section at each time step into the temperature parameters of the target wellbore.

[0242] For each well section, the first temperature field of the well section is formed based on the fluid temperature in the temperature parameters of the well section at each time step, and the first temperature field includes the fluid temperature of the well section at each time step; then, based on the multiple fluid temperatures included in the first temperature field, the wellbore pressure at each time step that matches each fluid temperature is determined, and then based on the wellbore pressure at each time step, the first pressure field of the well section is formed, and the first pressure field includes the wellbore pressure of the well section at each time step.

[0243] For each time step, based on the fluid temperature in the temperature parameters of each well section at the time step, the second temperature field of the time step is determined, and the second temperature field includes the fluid temperature of each well section at the time step; then based on the multiple fluid temperatures included in the second temperature field, the second pressure field of each well section at the time step that matches each fluid temperature is determined, and the second pressure field includes the wellbore pressure of each well section at the time step.

[0244] An embodiment of the present application provides a method for determining wellbore temperature parameters. Since the method divides the target wellbore into multiple well sections and multiple time steps, the temperature parameters of each well section at each time step can be determined through well temperature relationship data, thereby achieving accurate division of the temperature parameters of the target wellbore. In this way, the temperature parameters of each well section at each time step can be regarded as instantaneously stable temperature parameters, so that the temperature parameters match the actual well conditions of each well section at each time step, thereby improving the accuracy of the determined wellbore temperature parameters.

[0245] In the embodiment of the present application, the temperature parameters of the wellbore can be determined through the above steps 101-106; the embodiment of the present application can also adjust the preset wellbore pressure through the following steps 107-109.

[0246] Step 107: For each time step, the computer device obtains the wellhead pressure of the wellbore at the time step when the well section is the last well section.

[0247] The final fluid temperature is the fluid temperature of the last well section at this time step; wherein the final fluid temperature is obtained through the above steps 101-106. The wellhead pressure at this time step can be measured by a wellhead pressure measuring device; see Table 3, which is a wellhead pressure table of a target well, including the daily gas production of the target well, the casing pressure of the casing in the wellbore and the oil pressure of the oil pipe, and the oil pressure is used as the wellhead pressure.

[0248] Table 3

[0249]

[0250]

[0251]

[0252] Step 108: The computer device determines a final wellbore pressure matching the final fluid temperature based on the final fluid temperature.

[0253] Among them, the computer equipment determines the final wellbore pressure that matches the final fluid temperature based on the final fluid temperature through the wellbore flow pressure calculation model.

[0254] The computer equipment substitutes the final fluid temperature into the wellbore flow pressure calculation model to obtain the final wellbore pressure.

[0255] Step 109: The computer device adjusts the preset wellbore pressure based on the difference between the final wellbore pressure and the wellhead pressure.

[0256] The computer device has set a preset pressure accuracy value in advance; if the difference between the final wellbore pressure and the wellhead pressure is not greater than the preset pressure accuracy value, it means that the pressure has converged, and the temperature parameter of the wellbore obtained through steps 101-106 is highly accurate, and there is no need to adjust the preset wellbore pressure again. If the difference between the final wellbore pressure and the wellhead pressure is greater than the preset pressure accuracy value, it means that the pressure has not converged, and the wellbore pressure will be reset, and steps 101-109 will be repeated until the difference between the final wellbore pressure and the wellhead pressure is not greater than the preset accuracy value.

[0257] In another possible implementation, the computer device also sets a temperature preset accuracy value. If the difference between the final fluid temperature and the wellhead temperature is not greater than the temperature preset accuracy value, it means that the temperature has converged. The temperature parameter of the wellbore obtained through steps 101-106 has high accuracy and there is no need to adjust the wellbore preset pressure again. If the difference between the final fluid temperature and the wellhead temperature is greater than the temperature preset accuracy value, it means that the temperature has not converged. The preset wellbore pressure will be reset and steps 101-109 will be repeated until the difference between the final wellbore pressure and the wellhead pressure is not greater than the preset accuracy value.

[0258] The preset wellbore pressure may be adjusted in the following ways. In one possible implementation, if the pressure does not converge, the preset wellbore pressure is adjusted. In another possible implementation, if the temperature does not converge, the preset wellbore pressure is adjusted. In another possible implementation, if both the temperature and the pressure do not converge, the preset wellbore pressure is adjusted.

[0259] See also Figure 5 , Figure 5 The target wellbore temperature parameter determination method provided in the embodiment of the present application is applied to the process of each time step. The process includes: dividing the target wellbore into multiple well sections, determining the temperature parameters of the previous time step based on the preset target wellbore pressure, determining the high-pressure physical property parameters of each well section based on the temperature parameters of the previous time step, determining the target wellbore pressure of each well section matching the high-pressure physical property based on the target wellbore flow pressure calculation model, obtaining the second pressure field of the target wellbore including the target wellbore pressure of each well section at the time step, and then determining the pressure gradient of the target wellbore based on the second pressure field, and obtaining the second temperature field of the target wellbore including the target wellbore temperature of each well section at the time step based on the pressure gradient. If both the temperature and the pressure do not converge, adjust the preset pressure of the target wellbore, and repeat the above steps until both the temperature and the pressure converge. In this way, by adjusting the preset wellbore pressure, the accuracy of the temperature parameter determined based on the preset wellbore pressure can be improved.

[0260] The present application embodiment provides a wellbore temperature parameter determination device, see Figure 6 , the device comprises:

[0261] The first determination module 601 is used to determine multiple well sections of the target wellbore to be studied, where the multiple well sections are well sections divided sequentially from the bottom of the target wellbore to the wellhead;

[0262] The second determination module 602 is used to determine multiple time steps of the target wellbore, where the multiple time steps are time periods obtained by sequentially dividing the production time of the target wellbore;

[0263] A first acquisition module 603 is used to acquire the first time step parameter of each well section in each time step of each well section;

[0264] The second acquisition module 604 is used to acquire well temperature relationship data of the target well area where the target wellbore is located, and the well temperature relationship data is the relationship data between the time step parameter and the temperature parameter;

[0265] The third determination module 605 is used to determine the temperature parameter of the well section at the time step based on the first time step parameter and through the well temperature relationship data;

[0266] The fourth determination module 606 is used to determine the temperature parameter of the target wellbore based on the temperature parameter of each well section at each time step.

[0267] In a possible implementation, the second acquisition module 604 includes:

[0268] A first acquisition unit is used to acquire first equilibrium relationship data, second equilibrium relationship data and third equilibrium relationship data of a target well area, wherein the first equilibrium relationship data is the relationship data between temperature, time and heat flow rate when the fluid heat transfer between the formation and the wellbore of the target well area is in equilibrium, the second relationship data is the relationship data between temperature and heat flow rate when the fluid heat transfer between the wellbore and the target wellbore is in equilibrium, and the third relationship data is the relationship data between pressure gradient and heat flow rate when the fluid convection heat transfer of the formation is in equilibrium;

[0269] A convolution unit is used to convolve the first equilibrium relationship data to obtain convolution relationship data, where the convolution relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when heat transfer between the formation and the well wall is in equilibrium;

[0270] A first determination unit is used to determine the sum of the second equilibrium relationship data and the convolution relationship data to obtain fourth equilibrium relationship data, where the fourth equilibrium relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when the fluid heat transfer between the formation and the target wellbore is in equilibrium;

[0271] The second determining unit is used to determine the well temperature relationship data based on the third balance relationship data and the fourth balance relationship data.

[0272] In one possible implementation, the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data, and fluid temperature relationship data;

[0273] The second determining unit includes:

[0274] a splitting unit, used for splitting the fourth equilibrium relationship data into heat flow rate relationship data, instantaneous heat transfer relationship data and apparent heat flow rate relationship data, the heat flow rate relationship data is used for representing the relationship data relationship between the heat flow rate, instantaneous heat transfer coefficient and apparent heat flow rate of the target wellbore, the instantaneous heat transfer relationship data is used for representing the relationship data relationship between the instantaneous heat transfer coefficient and the time step time of the target wellbore, and the apparent heat flow rate relationship data is used for representing the relationship data relationship between the apparent heat flow rate, heat flow rate and time step time of the target wellbore;

[0275] The synthesis unit is used to synthesize the third equilibrium relationship data and the heat flow rate relationship data to obtain the fluid temperature relationship data.

[0276] In a possible implementation, the first time step parameter includes a pressure gradient of the time step, and the time step is not the first time step, then the first acquisition module 603 includes:

[0277] A second acquisition unit is used to acquire a first fluid temperature of a well section at a previous time step and a second fluid temperature of a previous well section at a time step;

[0278] a third determining unit, for determining a first wellbore pressure matching the first fluid temperature and a second wellbore pressure matching the second fluid temperature based on the first fluid temperature and the second fluid temperature, respectively;

[0279] The fourth determination unit is used to determine the pressure gradient based on the depth difference between the well section and the previous well section, the first wellbore pressure and the second wellbore pressure.

[0280] In a possible implementation, the first time step parameter includes an initial pressure gradient, the time step is the first time step, and the well section is the first well section, then the first acquisition module 603 includes:

[0281] A third acquisition unit, used to acquire an initial fluid temperature at the bottom of the wellbore and a preset wellbore pressure of the first well section;

[0282] a fifth determining unit, configured to determine, based on the initial fluid temperature, an initial wellbore pressure matching the initial fluid temperature;

[0283] The sixth determination unit is used to determine the initial pressure gradient based on the depth difference between the first well section and the bottom of the wellbore, the initial wellbore pressure and the preset wellbore pressure.

[0284] In a possible implementation, the device further includes:

[0285] A third acquisition module is used for acquiring, for each time step, the wellbore wellhead pressure and final fluid temperature of the target wellbore at the time step when the well section is the last well section, where the final fluid temperature is the fluid temperature of the last well section at the time step;

[0286] a fifth determination module, configured to determine, based on the final fluid temperature, a final wellbore pressure matching the final fluid temperature;

[0287] The adjustment module is used to adjust the preset wellbore pressure based on the difference between the final wellbore pressure and the wellhead pressure.

[0288] In a possible implementation, the temperature parameters of the well section at the time step include a first fluid temperature and a first heat flow rate, and the well temperature relationship data include heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data, and fluid temperature relationship data;

[0289] The first time step parameters include the pressure gradient of the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. If the time step is not the first time step, the third determination module 605 includes:

[0290] a seventh determination unit, for determining a first instantaneous heat transfer coefficient at the time step through instantaneous heat transfer relationship data based on the time step time of the time step, wherein the instantaneous heat transfer relationship data is used to represent a relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time;

[0291] an eighth determination unit, for determining a first apparent heat flow rate at a time step based on each heat flow rate from the first time step to the previous time step and each time step time from the first time step to the time step through apparent heat flow rate relationship data, wherein the apparent heat flow rate relationship data is used to represent a relationship data relationship between an apparent heat flow rate, a heat flow rate, and a time step time of a target wellbore;

[0292] A ninth determination unit is used to determine the first fluid temperature at the time step based on the boundary condition parameters, the first apparent heat flow rate and the pressure gradient through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the instantaneous heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore;

[0293] The tenth determination unit is used to determine the first heat flow rate at the time step based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore.

[0294] In a possible implementation, the temperature parameter of the well section at the time step includes the second fluid temperature and the second heat flow rate, and the well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data;

[0295] The first time step parameters include the initial pressure gradient of the time step, the initial time step time, the initial heat flow rate, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. The time step is the first time step and the well section is the first well section. The third determination module 605 includes:

[0296] an eleventh determining unit, for determining a second instantaneous heat transfer coefficient at the first time step through instantaneous heat transfer relationship data based on the initial time step;

[0297] a twelfth determining unit, for determining a second apparent heat flow rate at a first time step based on the initial heat flow rate and through the apparent heat flow rate relationship data;

[0298] a thirteenth determining unit, for determining the second fluid temperature at the first time step through the fluid temperature relationship data based on the boundary condition parameter, the second apparent heat flow rate and the initial pressure gradient;

[0299] The fourteenth determination unit is used to determine the second heat flow rate at the first time step based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature through the heat flow rate relationship data.

[0300] Figure 7 The block diagram of a computer device 700 provided by an exemplary embodiment of the present application is shown. The computer device 700 may be a portable mobile computer device, such as a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III), an MP4 player (Moving Picture Experts Group Audio Layer IV), a laptop computer or a desktop computer. The computer device 700 may also be referred to as a user device, a portable computer device, a laptop computer device, a desktop computer device, or other names.

[0301] Typically, the computer device 700 includes a processor 701 and a memory 702 .

[0302] The processor 701 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 701 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). The processor 701 may also include a main processor and a coprocessor. The main processor is a processor for processing data in the awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in the standby state. In some embodiments, the processor 701 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 701 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0303] The memory 702 may include one or more computer-readable storage media, which may be non-transitory. The memory 702 may also include a high-speed random access memory, and a non-volatile memory, such as one or more disk storage devices, flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in the memory 702 is used to store at least one instruction, which is used to be executed by the processor 701 to implement the wellbore temperature parameter determination method provided in the method embodiment of the present application.

[0304] In some embodiments, the computer device 700 may further optionally include: a peripheral device interface 703 and at least one peripheral device. The processor 701, the memory 702 and the peripheral device interface 703 may be connected via a bus or a signal line. Each peripheral device may be connected to the peripheral device interface 703 via a bus, a signal line or a circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 704, a display screen 705, a camera assembly 706, an audio circuit 707, a positioning assembly 708 and a power supply 709.

[0305] The peripheral device interface 703 may be used to connect at least one peripheral device related to I / O (Input / Output) to the processor 701 and the memory 702. In some embodiments, the processor 701, the memory 702, and the peripheral device interface 703 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 701, the memory 702, and the peripheral device interface 703 may be implemented on a separate chip or circuit board, which is not limited in this embodiment.

[0306] The radio frequency circuit 704 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The radio frequency circuit 704 communicates with communication networks and other communication devices through electromagnetic signals. The radio frequency circuit 704 converts electrical signals into electromagnetic signals for transmission, or converts received electromagnetic signals into electrical signals. Optionally, the radio frequency circuit 704 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, and the like. The radio frequency circuit 704 can communicate with other computer devices through at least one wireless communication protocol. The wireless communication protocol includes, but is not limited to: the World Wide Web, a metropolitan area network, an intranet, various generations of mobile communication networks (2G, 3G, 4G and 5G), a wireless local area network and / or a WiFi (Wireless Fidelity) network. In some embodiments, the radio frequency circuit 704 may also include circuits related to NFC (Near Field Communication), which is not limited in this application.

[0307] The display screen 705 is used to display the UI (User Interface). The UI may include graphics, text, icons, videos, and any combination thereof. When the display screen 705 is a touch display screen, the display screen 705 also has the ability to collect touch signals on the surface or above the surface of the display screen 705. The touch signal can be input to the processor 701 as a control signal for processing. At this time, the display screen 705 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, the display screen 705 can be one, set on the front panel of the computer device 700; in other embodiments, the display screen 705 can be at least two, respectively set on different surfaces of the computer device 700 or in a folding design; in other embodiments, the display screen 705 can be a flexible display screen, set on the curved surface or folding surface of the computer device 700. Even, the display screen 705 can also be set to a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 705 can be made of materials such as LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode, organic light-emitting diode).

[0308] The camera assembly 706 is used to capture images or videos. Optionally, the camera assembly 706 includes a front camera and a rear camera. Typically, the front camera is set on the front panel of the computer device, and the rear camera is set on the back of the computer device. In some embodiments, there are at least two rear cameras, which are any one of a main camera, a depth of field camera, a wide-angle camera, and a telephoto camera, so as to realize the fusion of the main camera and the depth of field camera to realize the background blur function, the fusion of the main camera and the wide-angle camera to realize panoramic shooting and VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, the camera assembly 706 may also include a flash. The flash can be a monochrome temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cold light flash, which can be used for light compensation at different color temperatures.

[0309] The audio circuit 707 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, and convert the sound waves into electrical signals and input them into the processor 701 for processing, or input them into the radio frequency circuit 704 to achieve voice communication. For the purpose of stereo acquisition or noise reduction, there can be multiple microphones, which are respectively arranged at different parts of the computer device 700. The microphone can also be an array microphone or an omnidirectional acquisition microphone. The speaker is used to convert the electrical signal from the processor 701 or the radio frequency circuit 704 into sound waves. The speaker can be a traditional film speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can not only convert the electrical signal into sound waves audible to humans, but also convert the electrical signal into sound waves inaudible to humans for purposes such as ranging. In some embodiments, the audio circuit 707 may also include a headphone jack.

[0310] Positioning component 708 is used to locate the current geographic location of computer device 700 to implement navigation or LBS (Location Based Service). Positioning component 708 can be a positioning component based on the US GPS (Global Positioning System), China's Beidou system or Russia's Galileo system.

[0311] The power supply 709 is used to power various components in the computer device 700. The power supply 709 can be an alternating current, a direct current, a disposable battery, or a rechargeable battery. When the power supply 709 includes a rechargeable battery, the rechargeable battery can be a wired rechargeable battery or a wireless rechargeable battery. A wired rechargeable battery is a battery that is charged through a wired line, and a wireless rechargeable battery is a battery that is charged through a wireless coil. The rechargeable battery can also be used to support fast charging technology.

[0312] In some embodiments, the computer device 700 further includes one or more sensors 710 , including but not limited to: an acceleration sensor 711 , a gyroscope sensor 712 , a pressure sensor 713 , a fingerprint sensor 714 , an optical sensor 715 , and a proximity sensor 716 .

[0313] The acceleration sensor 711 can detect the magnitude of acceleration on the three coordinate axes of the coordinate system established by the computer device 700. For example, the acceleration sensor 711 can be used to detect the components of gravity acceleration on the three coordinate axes. The processor 701 can control the display screen 705 to display the user interface in a horizontal view or a vertical view according to the gravity acceleration signal collected by the acceleration sensor 711. The acceleration sensor 711 can also be used to collect game or user motion data.

[0314] The gyro sensor 712 can detect the body direction and rotation angle of the computer device 700, and the gyro sensor 712 can cooperate with the acceleration sensor 711 to collect the user's 3D actions on the computer device 700. The processor 701 can implement the following functions based on the data collected by the gyro sensor 712: motion sensing (such as changing the UI according to the user's tilt operation), image stabilization during shooting, game control, and inertial navigation.

[0315] The pressure sensor 713 can be set on the side frame of the computer device 700 and / or the lower layer of the display screen 705. When the pressure sensor 713 is set on the side frame of the computer device 700, it can detect the user's grip signal of the computer device 700, and the processor 701 performs left and right hand recognition or shortcut operation according to the grip signal collected by the pressure sensor 713. When the pressure sensor 713 is set on the lower layer of the display screen 705, the processor 701 controls the operability controls on the UI interface according to the user's pressure operation on the display screen 705. The operability controls include at least one of a button control, a scroll bar control, an icon control, and a menu control.

[0316] The fingerprint sensor 714 is used to collect the user's fingerprint, and the processor 701 identifies the user's identity based on the fingerprint collected by the fingerprint sensor 714, or the fingerprint sensor 714 identifies the user's identity based on the collected fingerprint. When the user's identity is identified as a trusted identity, the processor 701 authorizes the user to perform relevant sensitive operations, which include unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings. The fingerprint sensor 714 can be set on the front, back, or side of the computer device 700. When a physical button or a manufacturer logo is set on the computer device 700, the fingerprint sensor 714 can be integrated with the physical button or the manufacturer logo.

[0317] The optical sensor 715 is used to collect the ambient light intensity. In one embodiment, the processor 701 can control the display brightness of the display screen 705 according to the ambient light intensity collected by the optical sensor 715. Specifically, when the ambient light intensity is high, the display brightness of the display screen 705 is increased; when the ambient light intensity is low, the display brightness of the display screen 705 is reduced. In another embodiment, the processor 701 can also dynamically adjust the shooting parameters of the camera assembly 706 according to the ambient light intensity collected by the optical sensor 715.

[0318] The proximity sensor 716, also called a distance sensor, is usually disposed on the front panel of the computer device 700. The proximity sensor 716 is used to collect the distance between the user and the front of the computer device 700. In one embodiment, when the proximity sensor 716 detects that the distance between the user and the front of the computer device 700 is gradually decreasing, the processor 701 controls the display screen 705 to switch from the screen-on state to the screen-off state; when the proximity sensor 716 detects that the distance between the user and the front of the computer device 700 is gradually increasing, the processor 701 controls the display screen 705 to switch from the screen-off state to the screen-on state.

[0319] Those skilled in the art will understand that Figure 7 The structure shown in the figure does not constitute a limitation on the computer device 700, and the computer device 700 may include more or less components than shown in the figure, or combine some components, or adopt a different arrangement of components.

[0320] On the other hand, a computer-readable storage medium is provided, in which at least one program code is stored, and the at least one program code is loaded and executed by a processor to implement the steps in the method for determining the wellbore temperature parameters of any of the above-mentioned implementation modes.

[0321] On the other hand, a computer program product or a computer program is provided, the computer program product or the computer program comprising a computer program code, the computer program code being stored in a computer-readable storage medium. A processor of a computer device reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code, so that the computer device performs the operations performed by the above-mentioned wellbore temperature parameter determination method.

[0322] In some embodiments, the computer program involved in the embodiments of the present application may be deployed and executed on a computer device, or on multiple computer devices located at one location, or on multiple computer devices distributed at multiple locations and interconnected by a communication network. Multiple computer devices distributed at multiple locations and interconnected by a communication network may constitute a blockchain system.

[0323] An embodiment of the present application provides a method for determining wellbore temperature parameters. Since the method divides the target wellbore into multiple well sections and multiple time steps, the temperature parameters of each well section at each time step can be determined through well temperature relationship data, thereby achieving accurate division of the temperature parameters of the target wellbore. In this way, the temperature parameters of each well section at each time step can be regarded as instantaneously stable temperature parameters, so that the temperature parameters match the actual well conditions of each well section at each time step, thereby improving the accuracy of the determined wellbore temperature parameters.

[0324] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for determining wellbore temperature parameters, characterized in that: The method comprises: Determine a plurality of well sections of a target wellbore to be studied, wherein the plurality of well sections are well sections divided sequentially from the bottom to the wellhead of the target wellbore; Determine a plurality of time steps of the target wellbore, wherein the plurality of time steps are time periods obtained by sequentially dividing the production time of the target wellbore; For each time step of each well section, obtaining a first time step parameter of the well section at the time step; Acquire well temperature relationship data of a target well area where the target wellbore is located, wherein the well temperature relationship data is relationship data between a time step parameter and a temperature parameter; Based on the first time step parameter, determine the temperature parameter of the well section at the time step through the well temperature relationship data; Determining the temperature parameter of the target wellbore based on the temperature parameter of each well section at each time step; The temperature parameters of the well section at the time step include a first fluid temperature and a first heat flow rate, and the well temperature relationship data include heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data; The first time step parameters include the pressure gradient at the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step of the time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. If the time step is not the first time step, then the temperature parameters of the well section at the time step are determined based on the first time step parameters and through the well temperature relationship data, including: Based on the time step time of the time step, determining a first instantaneous heat transfer coefficient at the time step through the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time; Based on each heat flow rate from the first time step to the previous time step of the time step and each time step time from the first time step to the time step, determining the first apparent heat flow rate at the time step through the apparent heat flow rate relationship data, the apparent heat flow rate relationship data being used to represent the relationship data relationship between the apparent heat flow rate, heat flow rate, and time step time of the target wellbore; Based on the boundary condition parameters, the first apparent heat flow rate and the pressure gradient, the first fluid temperature at the time step is determined through the fluid temperature relationship data, and the fluid temperature function is used to represent the relationship data between the fluid temperature, the instantaneous heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore; Based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature, determining the first heat flow rate at the time step through the heat flow rate relationship data, the heat flow rate relationship data being used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore; The temperature parameters of the well section at the time step include a second fluid temperature and a second heat flow rate, and the well temperature relationship data include heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data; The first time step parameters include the initial pressure gradient, initial time step time, initial heat flow rate, boundary condition parameters of the target wellbore and formation temperature corresponding to the well section at the time step, the time step is the first time step, and the well section is the first well section, then based on the first time step parameters, determining the temperature parameters of the well section at the time step through the well temperature relationship data includes: Based on the initial time step, determining a second instantaneous heat transfer coefficient at the first time step by using the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time; Based on the initial heat flow rate, determining a second apparent heat flow rate at the first time step through the apparent heat flow rate relationship data, the apparent heat flow rate relationship data being used to represent the relationship data relationship between the apparent heat flow rate, heat flow rate, and time step time of the target wellbore; Based on the boundary condition parameters, the second apparent heat flow rate and the initial pressure gradient, the second fluid temperature at the first time step is determined through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore; Based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature, the second heat flow rate at the first time step is determined through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, instantaneous heat transfer coefficient and apparent heat flow rate of the target wellbore.

2. A method for determining wellbore temperature parameters according to claim 1, characterized in that: The step of obtaining the well temperature relationship data of the target well area where the target wellbore is located includes: Acquire first equilibrium relationship data, second equilibrium relationship data, and third equilibrium relationship data of the target well area, wherein the first equilibrium relationship data is the relationship data between temperature, time, and heat flow rate when the fluid heat transfer between the formation and the well wall of the target well area is in equilibrium, the second equilibrium relationship data is the relationship data between temperature and heat flow rate when the fluid heat transfer between the well wall and the target wellbore is in equilibrium, and the third equilibrium relationship data is the relationship data between pressure gradient and heat flow rate when the fluid convection heat transfer of the formation is in equilibrium; Convolving the first equilibrium relationship data to obtain convolution relationship data, wherein the convolution relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when heat transfer equilibrium is achieved between the formation and the well wall; Determine the sum of the second equilibrium relationship data and the convolution relationship data to obtain fourth equilibrium relationship data, wherein the fourth equilibrium relationship data is relationship data between temperature, each time step time, and heat flow rate corresponding to each time step time when the fluid heat transfer between the formation and the target wellbore is in equilibrium; The well temperature relationship data is determined based on the third balance relationship data and the fourth balance relationship data.

3. A method for determining wellbore temperature parameters according to claim 2, characterized in that: The well temperature relationship data includes heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data; The determining the well temperature relationship data based on the third balance relationship data and the fourth balance relationship data comprises: Splitting the fourth equilibrium relationship data into the heat flux relationship data, the instantaneous heat transfer relationship data and the apparent heat flux relationship data, the heat flux relationship data is used to represent the relationship data relationship between the heat flux, the instantaneous heat transfer coefficient and the apparent heat flux of the target wellbore, the instantaneous heat transfer relationship data is used to represent the relationship data relationship between the instantaneous heat transfer coefficient and the time step of the target wellbore, the apparent heat flux relationship data is used to represent the relationship data relationship between the apparent heat flux, the heat flux and the time step of the target wellbore, and the fluid temperature function is used to represent the relationship data relationship between the fluid temperature, the instantaneous heat transfer coefficient, the apparent heat flux and the pressure gradient of the target wellbore; The third equilibrium relationship data and the heat flow rate relationship data are synthesized to obtain the fluid temperature relationship data.

4. A method for determining a wellbore temperature parameter according to claim 1, characterized in that: The first time step parameter includes the pressure gradient at the time step. If the time step is not the first time step, obtaining the first time step parameter of the well section at the time step includes: Acquire the first fluid temperature of the well section at the previous time step and the second fluid temperature of the previous well section at the current time step; determining a first wellbore pressure matching the first fluid temperature and a second wellbore pressure matching the second fluid temperature based on the first fluid temperature and the second fluid temperature, respectively; The pressure gradient is determined based on a depth difference between the well section and the previous well section, the first wellbore pressure, and the second wellbore pressure.

5. A method for determining wellbore temperature parameters according to claim 1, characterized in that: The parameters of the first time step include an initial pressure gradient. The time step is the first time step, and the well section is the first well section. Then, obtaining the first time step parameters of the well section at the time step includes: Obtaining an initial fluid temperature at the bottom of the wellbore and a preset wellbore pressure of the first well section; Based on the initial fluid temperature, determining an initial wellbore pressure matching the initial fluid temperature; The initial pressure gradient is determined based on the depth difference between the first well section and the bottom of the wellbore, the initial wellbore pressure and the preset wellbore pressure.

6. A method for determining wellbore temperature parameters according to claim 5, characterized in that: The method further comprises: For each time step, when the well section is the last well section, obtaining the wellhead pressure and final fluid temperature of the target wellbore at the time step, wherein the final fluid temperature is the fluid temperature of the last well section at the time step; Based on the final fluid temperature, determining a final wellbore pressure matching the final fluid temperature; The preset wellbore pressure is adjusted based on the difference between the final wellbore pressure and the wellhead pressure.

7. A device for determining a wellbore temperature parameter, characterized in that: The device comprises: A first determination module is used to determine a plurality of well sections of a target wellbore to be studied, wherein the plurality of well sections are well sections divided sequentially from the bottom to the wellhead of the target wellbore; A second determination module is used to determine a plurality of time steps of the target wellbore, wherein the plurality of time steps are time periods obtained by sequentially dividing the production time of the target wellbore; A first acquisition module is used to acquire, for each time step of each well section, a first time step parameter of the well section at the time step; A second acquisition module is used to acquire well temperature relationship data of a target well area where the target wellbore is located, wherein the well temperature relationship data is relationship data between a time step parameter and a temperature parameter; A third determination module is used to determine the temperature parameter of the well section at the time step based on the first time step parameter and through the well temperature relationship data; A fourth determination module, configured to determine the temperature parameter of the target wellbore based on the temperature parameter of each well section at each time step; The temperature parameters of the well section at the time step include a first fluid temperature and a first heat flow rate, and the well temperature relationship data include heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data; The first time step parameters include the pressure gradient at the time step, each time step time from the first time step to the time step, each heat flow rate from the first time step to the previous time step of the time step, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section. If the time step is not the first time step, the third determination module includes: a seventh determining unit, for determining a first instantaneous heat transfer coefficient at the time step based on the time step time of the time step by means of the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent a relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time; an eighth determination unit, configured to determine a first apparent heat flow rate at the time step based on each heat flow rate from the first time step to the previous time step of the time step and each time step time from the first time step to the time step, through the apparent heat flow rate relationship data, wherein the apparent heat flow rate relationship data is used to represent the relationship data relationship between the apparent heat flow rate, the heat flow rate, and the time step time of the target wellbore; a ninth determining unit, configured to determine the first fluid temperature at the time step based on the boundary condition parameter, the first apparent heat flow rate and the pressure gradient through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore; a tenth determining unit, configured to determine the first heat flow rate at the time step based on the first apparent heat flow rate, the first instantaneous heat transfer coefficient, the first fluid temperature and the formation temperature through the heat flow rate relationship data, wherein the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore; The temperature parameters of the well section at the time step include a second fluid temperature and a second heat flow rate, and the well temperature relationship data include heat flow rate relationship data, instantaneous heat transfer relationship data, apparent heat flow rate relationship data and fluid temperature relationship data; The first time step parameters include the initial pressure gradient, the initial time step time, the initial heat flow rate, the boundary condition parameters of the target wellbore and the formation temperature corresponding to the well section at the time step, the time step is the first time step, and the well section is the first well section, then the third determination module includes: an eleventh determining unit, for determining a second instantaneous heat transfer coefficient at the first time step based on the initial time step by means of the instantaneous heat transfer relationship data, wherein the instantaneous heat transfer relationship data is used to represent a relationship data relationship between the instantaneous heat transfer coefficient of the target wellbore and the time step time; a twelfth determining unit, for determining a second apparent heat flow rate at the first time step based on the initial heat flow rate and through the apparent heat flow rate relationship data, wherein the apparent heat flow rate relationship data is used to represent a relationship data relationship between the apparent heat flow rate, the heat flow rate, and the time step time of the target wellbore; a thirteenth determining unit, for determining the second fluid temperature at the first time step based on the boundary condition parameter, the second apparent heat flow rate and the initial pressure gradient through the fluid temperature relationship data, wherein the fluid temperature function is used to represent the relationship data between the fluid temperature, the transient heat transfer coefficient, the apparent heat flow rate and the pressure gradient of the target wellbore; A fourteenth determination unit is used to determine the second heat flow rate at the first time step based on the second apparent heat flow rate, the second instantaneous heat transfer coefficient, the second fluid temperature and the formation temperature through the heat flow rate relationship data, and the heat flow rate relationship data is used to represent the relationship data relationship between the heat flow rate, the instantaneous heat transfer coefficient and the apparent heat flow rate of the target wellbore.

8. A computer device, characterized in that: The computer device includes one or more processors and one or more memories, wherein at least one instruction is stored in the one or more memories, and the at least one instruction is loaded and executed by the one or more processors to implement the operations performed by the wellbore temperature parameter determination method as described in any one of claims 1 to 6.

Images