Method, device and equipment for determining temperature field data

Abstract

The invention discloses a method, a device and equipment for determining temperature field data, and relates to the technical field of salt cavern gas storage construction. After structural parameters of a shaft arranged in the target salt cavern gas storage and physical parameters of brine in the target salt cavern gas storage are obtained, temperature field data of the brine in the shaft are determined based on the structural parameters and the physical parameters of the brine; the temperature field data of the brine in the shaft comprises the temperatures of the brine in multiple positions in the shaft; and according to the temperature field data of the shaft and the physical parameters of the brine, determining the temperature field data of the brine in the target salt cavern gas storage.

Description

Technical Field

[0001] The present application relates to the technical field of salt cavern gas storage construction, and particularly to a method, device, and equipment for determining temperature field data. Background Art

[0002] The construction of salt cavern gas storage mainly adopts the water-solution cavity-forming method, that is, injecting clear water into the salt cavern. Under the action of the concentration difference, the salt rock on the cavity wall will dissolve in the injected clear water, and then the wall surface gradually extends outward, and the cavity volume gradually increases. It can be considered that the construction rate of the salt cavern gas storage depends on the dissolution rate of the salt rock on the cavity wall.

[0003] Related research has shown that temperature has a great influence on the dissolution rate of salt rock. However, in the publicly available technologies and research, the temperature distribution of the brine in the cavity is not taken as a factor affecting the cavity expansion. Especially for deep salt caverns, there is a large difference between the initial temperature of the injected brine and the in-situ formation temperature of the salt cavern. Ignoring the temperature change will bring greater errors to the prediction of the cavity shape. In addition, predicting the non-uniform distribution of the brine temperature field in the cavity during the water-solution cavity-forming process can more accurately predict the dissolution rate field at the depth positions of different temperature measurement points on the wall surface. Therefore, how to construct a method for determining the temperature field of brine in a salt cavern gas storage has become an urgent technical problem to be solved. Summary of the Invention

[0004] The purpose of the present application is to provide a method, device, and equipment for determining temperature field data, aiming to determine the temperature field data of brine in a salt cavern gas storage.

[0005] To achieve the above object, the present application adopts the following technical solutions:

[0006] In a first aspect, the present application provides a method for determining temperature field data, including: obtaining the structural parameters of the wellbore set in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage; determining the temperature field data of the brine in the wellbore based on the structural parameters and the physical parameters of the brine; the temperature field data of the brine in the wellbore includes the temperatures of the brine at multiple positions in the wellbore; determining the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine.

[0007] According to the above technical means, the present application can determine the temperature field data in the wellbore according to the structural parameters of the wellbore set in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage; determine the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine, realizing the accurate determination of the temperature field of the brine in the target salt cavern gas storage, with simple and scientific calculation, and providing strong data support for the fine prediction of the cavity shape of the salt cavern gas storage during the construction process.

[0008] In a possible implementation, an intermediate pipe is further provided in the wellbore. Based on the structural parameters and the physical parameters of the brine, the temperature field data of the wellbore is determined, including: according to the structural parameters, determining the first flow velocity of the brine in the central pipe and the second flow velocity in the annular space between the intermediate pipe and the central pipe; based on the first flow velocity, the physical parameters of the brine, and the structural parameters, determining the first temperature field data of the brine in the central pipe; based on the second flow velocity and the physical parameters of the intermediate pipe, determining the second temperature field data of the brine in the annular space; and based on the first temperature field data and the second temperature field data, determining the temperature field data of the brine in the wellbore.

[0009] According to the above technical means, the present application determines the temperature field data of the brine in the wellbore based on the first temperature field data of the brine in the central pipe and the second temperature field data of the brine in the central pipe, making the temperature field data more accurate, facilitating the subsequent data calculation, and improving the accuracy of the method.

[0010] In a possible implementation, the first flow velocity satisfies a first preset formula, and the second flow velocity satisfies a second preset formula. The first preset formula is:

[0011]

[0012] where v bi represents the flow velocity of the brine in the central pipe, S represents the cavity-forming displacement, and the cavity-forming displacement refers to the volume of fluid injected into or discharged from the wellbore per unit time; r in represents the inner radius of the central pipe;

[0013] The second preset formula is:

[0014]

[0015] where v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, S represents the cavity-forming displacement, r in represents the inner radius of the central pipe, and r mi represents the inner radius of the intermediate pipe.

[0016] In a possible implementation, the first temperature field data satisfies a third preset formula. The third preset formula is:

[0017]

[0018] where T in represents the temperature of the brine in the central pipe, t represents the cavity-forming operation time, v bi represents the flow velocity of the brine in the central pipe, z represents the depth of the temperature measurement point, Uin Denotes the heat transfer coefficient of the central pipe, C b Denotes the specific heat capacity of the brine, ρ b Denotes the density of the brine, A in Denotes the cross-sectional area of the central pipe, T mi Denotes the temperature of the brine in the annular space between the intermediate pipe and the central pipe.

[0019] In a possible implementation, the second temperature field data satisfies a fourth preset formula, and the fourth preset formula is:

[0020]

[0021] Wherein, T mi Denotes the temperature of the brine in the annular space between the intermediate pipe and the central pipe, t denotes the operation time of cavity formation, v bm Denotes the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, z denotes the depth of the temperature measurement point, T in Denotes the temperature of the brine in the central pipe, T e Denotes the formation temperature, A and B are coefficients;

[0022] The coefficients A and B satisfy a fifth preset formula, and the fifth preset formula is:

[0023]

[0024] Wherein, r in Denotes the inner radius of the central pipe, r mi Denotes the inner radius of the intermediate pipe, C b Denotes the specific heat capacity of the brine, ρ b Denotes the density of the brine, U in Denotes the heat transfer coefficient of the central pipe, U mi Denotes the heat transfer coefficient of the intermediate pipe, A mi Denotes the cross-sectional area of the annular space between the intermediate pipe and the central pipe.

[0025] In a possible implementation, based on the temperature field data of the wellbore and the physical parameters of the brine, determine the temperature field data of the brine in the target salt cavern gas storage, including: based on the temperature field data of the wellbore and the physical parameters of the brine, determine the velocity distribution of the brine in the cavity of the target salt cavern gas storage; based on the velocity distribution and the physical parameters of the brine, determine the temperature field data of the brine in the salt cavern gas storage.

[0026] Based on the above technical means, the velocity distribution of the brine in the cavity is determined according to the temperature field data of the wellbore and the physical parameters of the brine. Then, based on the velocity distribution and the physical parameters of the brine, the temperature field data of the brine in the wellbore is used as a calculation constraint condition to determine the temperature field data of the brine in the salt cavern gas storage, further enhancing the accuracy and precision of the data.

[0027] In a possible implementation, the velocity distribution of the brine in the cavity of the target salt cavern gas storage satisfies the sixth preset formula, and the sixth preset formula is:

[0028]

[0029] where ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the cavity formation operation time, p represents the brine pressure, μ represents the viscosity of the brine, L represents the unit matrix, and F represents the external force acting on the brine.

[0030] In a possible implementation, the temperature field data of the brine in the salt cavern gas storage satisfies the seventh preset formula, and the seventh preset formula is:

[0031]

[0032] where T b represents the temperature of the brine in the cavity, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the cavity formation operation time, k b represents the thermal conductivity of the brine, and Q b represents the comprehensive heat transfer rate between the brine and the surrounding rock wall.

[0033] In a second aspect, the present application provides a device for determining temperature field data, and the device includes: an acquisition module and a determination module.

[0034] The acquisition module is configured to acquire the structural parameters of the wellbore provided in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage;

[0035] The determination module is configured to determine the temperature field data of the brine in the wellbore based on the structural parameters and the physical parameters of the brine;

[0036] The determination module is further configured to determine the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine.

[0037] In a possible implementation, a determining module is provided. The wellbore is also provided with an intermediate pipe. Based on the structural parameters and the physical parameters of the brine, the temperature field data of the wellbore is determined, including: according to the structural parameters, determining the first flow velocity of the brine in the central pipe and the second flow velocity in the annular space between the intermediate pipe and the central pipe; based on the first flow velocity, the physical parameters of the brine, and the structural parameters, determining the first temperature field data of the brine in the central pipe; based on the second flow velocity and the physical parameters of the intermediate pipe, determining the second temperature field data of the brine in the annular space; and based on the first temperature field data and the second temperature field data, determining the temperature field data of the brine in the wellbore.

[0038] In a possible implementation, the first flow velocity satisfies a first preset formula, and the second flow velocity satisfies a second preset formula. The first preset formula is:

[0039]

[0040] where v bi represents the flow velocity of the brine in the central pipe, S represents the cavity-forming displacement, and the cavity-forming displacement refers to the volume of fluid injected into or discharged from the wellbore per unit time, and r in represents the inner radius of the central pipe. The second preset formula is:

[0041]

[0042] where v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, S represents the cavity-forming displacement, r in represents the inner radius of the central pipe, and r mi represents the inner radius of the intermediate pipe.

[0043] In a possible implementation, the first temperature field data satisfies a third preset formula. The third preset formula is:

[0044]

[0045] where T in represents the temperature of the brine in the central pipe, t represents the cavity-forming operation time, v bi represents the flow velocity of the brine in the central pipe, z represents the depth of the temperature measurement point, U in represents the heat transfer coefficient of the central pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, A in represents the cross-sectional area of the central pipe, and T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe.

[0046] In a possible implementation, the second temperature field data satisfies a fourth preset formula, and the fourth preset formula is:

[0047]

[0048] wherein, T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe, t represents the cavity formation operation time, v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, z represents the depth of the temperature measurement point, T in represents the temperature of the brine in the central pipe, T e represents the formation temperature, and a and B are coefficients;

[0049] The coefficients A and B satisfy a fifth preset formula, and the fifth preset formula is:

[0050]

[0051] wherein, r in represents the inner radius of the central pipe, r mi represents the inner radius of the intermediate pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, U in represents the heat transfer coefficient of the central pipe, U mi represents the heat transfer coefficient of the intermediate pipe, A mi represents the cross-sectional area of the annular space between the intermediate pipe and the central pipe of the intermediate pipe.

[0052] In a possible implementation, the determination module determines the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine, including: determining the velocity distribution of the brine in the cavity of the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine; and determining the temperature field data of the brine in the salt cavern gas storage according to the velocity distribution and the physical parameters of the brine.

[0053] In a possible implementation, the velocity distribution of the brine in the cavity of the target salt cavern gas storage satisfies a sixth preset formula, and the sixth preset formula is:

[0054]

[0055] wherein, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the cavity formation operation time, p represents the brine pressure, μ represents the viscosity of the brine, I represents the identity matrix, and F represents the external force applied to the brine.

[0056] In a possible implementation, the temperature field data of the brine in the salt cavern gas storage reservoir satisfies a seventh preset formula, and the seventh preset formula is:

[0057]

[0058] Wherein, T b represents the temperature of the brine in the cavity, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, k b represents the thermal conductivity of the brine, and Q b represents the comprehensive heat transfer rate between the brine and the surrounding rock wall.

[0059] In a third aspect, the present application provides an electronic device, which includes: a processor and a communication interface. The communication interface is coupled to the processor, and the processor is configured to run a computer program or instruction to implement the pipeline detection method described in the first aspect and any possible implementation manner of the first aspect. BRIEF DESCRIPTION OF THE DRAWINGS

[0060] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following will briefly introduce the drawings required for the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present application. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts.

[0061] Figure 1 It is a schematic structural diagram of a salt cavern gas storage reservoir provided in this embodiment;

[0062] Figure 2 It is a flowchart of a method for determining temperature field data provided in this embodiment;

[0063] Figure 3 It is a flowchart of another method for determining temperature field data provided in this embodiment;

[0064] Figure 4 It is a schematic structural diagram of a device for determining temperature field data provided in this embodiment. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0065] The following will clearly and completely describe the technical solutions in the embodiments of the present application with reference to the drawings in the embodiments of the present application. Obviously, the described embodiments are only some embodiments of the present application, rather than all embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative efforts belong to the scope of protection of the present application.

[0066] In the description of the present application, it should be understood that the orientation or positional relationship indicated by the terms "upper", "lower", "left", "right", "front", "rear", "inner", "outer", etc. is based on the orientation or relative positional relationship shown in the drawings. It is only for the convenience of describing the present application and simplifying the description, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation. Therefore, it should not be construed as a limitation to the present application. Without special instructions, under the condition of satisfying the relative positional relationship shown in the drawings, the above-mentioned directional descriptions can be flexibly set during the actual application process.

[0067] The terms "first" and "second" are used only for descriptive purposes and cannot be construed as indicating or implying relative importance or implicitly specifying the quantity of the indicated technical features. Thus, features defined with "first" and "second" may explicitly or implicitly include one or more of such features. In the description of the present application, unless otherwise specified, the meaning of "a plurality" is two or more.

[0068] In the description of the present application, it should be noted that unless otherwise clearly specified and limited, the terms "installed", "connected", "connected", and "communicated" should be understood in a broad sense. For example, it may be a fixed connection, a detachable connection, or an integral connection. It may be directly connected or indirectly connected through an intermediate medium, and it may be the communication inside two elements. For those of ordinary skill in the art, the specific meanings of the above terms in the present application can be understood according to specific situations.

[0069] In the embodiments of the present application, the term "comprising", "including" or any other variant thereof is intended to cover non-exclusive inclusion, so that a process, article or device including a series of elements not only includes those elements, but also includes other elements not explicitly listed, or further includes elements inherent to such process, article or device. Without further limitation, the element defined by the statement "including one..." does not exclude the existence of another identical element in the process, article or device including the element.

[0070] In the embodiments of the present application, words such as "exemplary" or "for example" are used to represent examples, illustrations or explanations. Any embodiment or design solution described as "exemplary" or "for example" in the embodiments of the present application should not be construed as being more preferred or having more advantages than other embodiments or design solutions. Exactly, using words such as "exemplary" or "for example" is intended to present relevant concepts in a specific manner.

[0071] In the description of this specification, specific features, structures, materials or characteristics may be combined in a suitable manner in any one or more embodiments or examples.

[0072] Exemplarily,Figure 1 The structural schematic diagram of a salt cavern gas storage provided by an embodiment of the present application is shown.

[0073] Among them, the salt cavern gas storage includes a flowmeter 101, a wellhead thermometer 102, a cement sheath 103, a casing 104, an intermediate pipe 105, a central pipe 106, a cavity 107, brine 108, a formation 109, a signal transmission cable 110, a signal receiver 111, and a terminal temperature field prediction system 112.

[0074] Among them, the flowmeter 101 and the wellhead thermometer 102 are connected to the signal receiver 111 and the terminal temperature field prediction system 112 through the signal transmission cable 110.

[0075] Among them, the wellbore structure arranged in the salt cavern gas storage includes a cement sheath 103, a casing 104, an intermediate pipe 105, and a central pipe 106.

[0076] Among them, the terminal temperature field prediction system 112 includes a water injection detection system, a wellbore temperature field prediction system, and a cavity temperature field prediction system. These systems will be specifically described below.

[0077] 1-1. Water injection detection system.

[0078] The water injection detection system can be used to detect the operation dynamics of the deep salt cavern gas storage in real time, including but not limited to data such as wellhead pressure, wellhead temperature, water injection rate, and physical properties of brine.

[0079] 1-2. Wellbore temperature field prediction system.

[0080] The wellbore temperature field prediction system can be used to perform numerical calculations of brine flow and heat transfer equations based on the received data and in combination with the basic parameters of the wellbore composite structure.

[0081] 1-3. Cavity temperature field prediction system.

[0082] The cavity temperature field prediction system can be used to solve the forced convection law of brine in the cavity based on the received wellbore temperature field prediction results, and then calculate the coupled heat transfer between the brine and the surrounding rock, and finally realize the accurate calculation of the temperature field of the brine in the target salt cavern gas storage.

[0083] As Figure 2 shown, an embodiment of the present application provides a method for determining temperature field data, and the method includes: S201-S203.

[0084] S201. Obtain the structural parameters of the wellbore arranged in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage.

[0085] Among them, the structural parameters of the wellbore set in the target salt cavern gas storage include the structural parameters of the central pipe and the intermediate pipe. The structural parameters of the central pipe may include the inner radius of the central pipe, the depth of the temperature measurement points required for the central pipe, the cross-sectional area of the central pipe, and the heat transfer coefficient of the central pipe. The structural parameters of the intermediate pipe may include the inner radius of the intermediate pipe and the cross-sectional area of the annular space between the intermediate pipe and the central pipe.

[0086] Among them, the physical parameters of the brine include the specific heat capacity of the brine, the density of the brine, the pressure of the brine, the viscosity of the brine, and the thermal conductivity of the brine.

[0087] In a possible implementation, the structural parameters of the wellbore set in the target salt cavern gas storage are determined according to the project information of the target salt cavern gas storage. And a water injection monitoring system is set in the target salt cavern gas storage.

[0088] The water injection detection system can detect the physical properties of the injected fresh water and the discharged brine in real time and monitor the operation dynamics of the target salt cavern gas storage in real time, and transmit the monitored data to the wellbore temperature field prediction system and the cavity temperature field prediction system.

[0089] S202. Based on the structural parameters and the physical parameters of the brine, determine the temperature field data of the brine in the wellbore.

[0090] Among them, the temperature field data of the brine in the wellbore includes the temperature of each point of the brine in the central pipe or the temperature of each point in the annular region between the intermediate pipe and the central pipe.

[0091] In a possible implementation, the wellbore temperature field prediction system determines the first flow velocity and the second flow velocity of the brine in the wellbore according to the structural parameters of the wellbore set in the salt cavern gas storage; determines the temperature data of each point of the brine in the wellbore according to the first flow velocity and the second flow velocity, and determines the temperature field data of the brine in the wellbore according to the temperature data.

[0092] S203. According to the temperature field data in the wellbore and the physical parameters of the brine, determine the temperature field data of the brine in the salt cavern gas storage.

[0093] Among them, the temperature field data of the brine in the salt cavern gas storage includes the temperature of each point of the brine in the salt cavern gas storage.

[0094] In a possible implementation, the cavity temperature field prediction system determines the velocity distribution of the brine in the cavity of the target salt cavern gas storage according to the physical parameters of the brine uploaded by the water injection detection system, and further determines the temperature of each point of the brine in the salt cavern gas storage according to the above velocity distribution and with the temperature field data in the wellbore uploaded by the wellbore temperature field prediction system as a limiting condition, so as to determine the temperature field data of the brine in the salt cavern gas storage.

[0095] According to the above technical means, the present application can determine the temperature field data of the brine in the target salt cavern gas storage based on the structural parameters of the wellbore set in the target salt cavern gas storage, the physical parameters of the brine in the target salt cavern gas storage, and the temperature field data of the brine in the wellbore. Under limited existing data, based on a complete theoretical model, it realizes the fine prediction of the temperature field of the brine in the target salt cavern gas storage, with simple and scientific calculation, and provides strong data support for the fine prediction of the cavity shape of the salt cavern gas storage during the construction process of the salt cavern gas storage.

[0096] As Figure 3 shown, in the method for determining the temperature field data provided by the embodiment of the present application, the above S202 may specifically include: S301 - S302.

[0097] S301. Based on the structural parameters of the wellbore set in the target salt cavern gas storage and the physical parameters of the brine, determine the temperature field data of the brine in the wellbore.

[0098] In a possible implementation manner, the wellbore temperature field prediction system determines the first flow velocity of the brine in the central pipe and the second flow velocity of the brine in the annular space between the intermediate pipe and the central pipe according to the structural parameters of the wellbore set in the target salt cavern gas storage. According to the first flow velocity, the structural parameters, and the physical parameters of the brine uploaded by the water injection detection system, determine the first temperature field data of the brine in the central pipe. According to the second flow velocity and the physical parameters of the intermediate pipe, determine the second temperature field data of the brine in the annular space. According to the first temperature field data and the second temperature field data, determine the temperature field data of the brine in the wellbore, and upload the temperature field data of the brine in the wellbore to the cavity temperature field prediction system.

[0099] Among them, the first temperature field data of the brine in the central pipe refers to that during the solution cavity formation by water injection, the fresh water injected into the cavity moves downward, and during this process, continuous heat exchange will occur with the annular space between the intermediate pipe and the central pipe. During this process, the temperatures of each point of the brine in the central pipe form the first temperature field data.

[0100] Among them, the second temperature field data of the brine in the annular space refers to that the brine in the annular space between the intermediate pipe and the central pipe will not only exchange heat with the fresh water in the central pipe, but also exchange heat with the formation. During this process, the temperatures of each point of the brine in the annular space between the intermediate pipe and the central pipe form the second temperature field data.

[0101] Among them, solution cavity formation by water injection refers to the core technology of the construction of the salt cavern gas storage, which means forming a gas storage cave by injecting fresh water into the underground salt layer to dissolve the salt rock. For the detailed technology, reference can be made to the existing technology and will not be elaborated here.

[0102] Specifically, during the process of solution mining for cavern formation, there are two methods: positive circulation and reverse circulation. In positive circulation, fresh water is injected through the central pipe into the cavity and the brine returns through the intermediate pipe. In reverse circulation, fresh water is injected through the intermediate pipe into the cavity and the brine returns through the central pipe. Since the mathematical calculation models for positive circulation and reverse circulation are the same, only positive circulation is taken as an example here.

[0103] In a possible implementation, the wellbore temperature field prediction system determines the first flow velocity of the brine in the central pipe according to the structural parameters of the wellbore. The first flow velocity satisfies the following formula (1):

[0104]

[0105] where v bi represents the flow velocity of the brine in the central pipe, S represents the solution mining displacement, and r in represents the inner radius of the central pipe.

[0106] The wellbore temperature prediction system determines the second flow velocity of the brine in the annular space between the intermediate pipe and the central pipe according to the structural parameters. The second flow velocity satisfies the following formula (2):

[0107]

[0108] where v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, S represents the solution mining displacement, r in represents the inner radius of the central pipe, and r mi represents the inner radius of the intermediate pipe.

[0109] Furthermore, the wellbore temperature field prediction system determines the first temperature field data of the brine in the central pipe according to the first flow velocity, the structural parameters of the wellbore set in the salt cavern gas storage, and the physical parameters of the brine uploaded by the water injection detection system. The first temperature field data satisfies the following formula (3):

[0110]

[0111] where T in represents the temperature of the brine in the central pipe, t represents the operation time of solution mining, v bi represents the flow velocity of the brine in the central pipe, z represents the depth of the temperature measurement point, U in represents the heat transfer coefficient of the central pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, A in represents the cross-sectional area of the central pipe, and T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe.

[0112] Determine the second temperature field data of the brine in the annular space according to the second flow velocity and the physical parameters of the intermediate pipe. The second temperature field data satisfies the following formula four:

[0113]

[0114] Among them, T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe, t represents the operation time of cavity formation, v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, z represents the depth of the temperature measurement point, T in represents the temperature of the brine in the central pipe, T e represents the formation temperature, and A and B are coefficients.

[0115] In a possible implementation, the coefficients A and B satisfy the following formula five:

[0116]

[0117] Among them, r in represents the inner radius of the central pipe, r mi represents the inner radius of the intermediate pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, U in represents the heat transfer coefficient of the central pipe, U mi represents the heat transfer coefficient of the intermediate pipe, A mi represents the cross-sectional area of the annular space between the intermediate pipe and the central pipe.

[0118] Furthermore, the wellbore temperature field prediction system can determine the temperature data of each point of the brine in the wellbore according to the first temperature field data of the brine in the central pipe and the second temperature field data of the brine in the annular space between the intermediate pipe and the central pipe, so as to determine the temperature field data of the brine in the wellbore, and upload the temperature field data of the brine in the wellbore to the cavity temperature field prediction system.

[0119] S302. Determine the temperature field data of the brine in the salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine.

[0120] Among them, the temperature field data of the brine in the salt cavern gas storage includes the temperatures of multiple position points of the brine in the salt cavern gas storage.

[0121] In a possible implementation, the cavity temperature field prediction system determines the velocity distribution of the brine in the cavity based on the physical parameters of the brine uploaded by the water injection detection system; based on the velocity distribution of the brine in the cavity and the physical properties of the brine, and using the temperature field data of the brine in the wellbore as a constraint condition for determining the mathematical model of the temperature field of the brine in the salt cavern gas storage, it determines the temperature at each point in the salt cavern gas storage and thus obtains the temperature field data of the brine in the salt cavern gas storage.

[0122] Among them, the velocity distribution of the brine in the cavity includes the flow velocity of the brine at each point in the cavity of the target salt cavern gas storage.

[0123] Specifically, the cavity temperature field prediction system determines the velocity distribution of the brine in the cavity according to the physical parameters of the brine. The flow of the brine in the cavity is still mainly dominated by forced convection, and the velocity distribution of the brine in the cavity satisfies the following formula six:

[0124] [[ID=९]]

[0125] Among them, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, p represents the brine pressure, μ represents the viscosity of the brine, I represents the unit matrix, and F represents the external force received by the brine.

[0126] Furthermore, the heat transfer form of the brine in the cavity mainly includes the forced convection heat transfer caused and the heat exchange with the surrounding rock. The cavity temperature field prediction system can use the temperature field data of the brine in the wellbore as a constraint condition, and based on the velocity distribution of the brine in the cavity and the physical parameters of the brine, determine the temperature at each point of the brine in the salt cavern gas storage.

[0127] The temperature at each point of the brine in the salt cavern gas storage satisfies the following formula seven:

[0128]

[0129] Among them, T b represents the temperature of the brine in the cavity, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, k b represents the thermal conductivity of the brine, Q b represents the comprehensive heat transfer rate between the brine and the surrounding rock wall.

[0130] Among them, the comprehensive heat transfer rate between the brine and the surrounding rock wall satisfies the following formula eight:

[0131] Q b =2πrU we (T e -T b ) Formula eight.

[0132] Among them, U we represents the comprehensive heat transfer coefficient between water and the surrounding rock wall, and T e represents the formation temperature, and T b represents the temperature of the brine in the cavity.

[0133] Based on the temperatures at various points of the brine in the salt cavern gas storage, the cavity temperature field prediction system combines the temperatures at various points to determine the temperature field data of the brine in the salt cavern gas storage.

[0134] Under the premise of no contradiction, the various solutions in the above embodiments of the present application can be combined.

[0135] The embodiments of the present application can divide the device management device into functional modules or functional units according to the above method examples. For example, corresponding to each function, each functional module or functional unit can be divided, or two or more functions can be integrated into one processing module. The above integrated module can be implemented in the form of hardware or in the form of a software functional module or functional unit. Among them, the division of modules or units in the embodiments of the present application is illustrative, only a logical function division, and there can be other division methods in actual implementation.

[0136] In the case of dividing each functional module corresponding to each function, Figure 4 it is a device for determining temperature field data provided by the present application. As Figure 4 shown, the device 40 for determining temperature field data can be used to execute Figure 2 , Figure 3 the method for determining temperature field data shown. The device for determining temperature field data includes: an acquisition module 401 and a determination module 402.

[0137] The acquisition module 401 is used to acquire the structural parameters of the wellbore set in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage;

[0138] The determination module 402 is used to determine the temperature field data of the brine in the wellbore based on the structural parameters and the physical parameters of the brine;

[0139] The determination module 402 is further used to determine the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine.

[0140] In a possible implementation, a determining module 402 is provided. An intermediate pipe is also arranged in the wellbore. Based on the structural parameters and the physical parameters of the brine, the temperature field data of the wellbore is determined, including: according to the structural parameters, determining the first flow velocity of the brine in the central pipe and the second flow velocity in the annular space between the intermediate pipe and the central pipe; based on the first flow velocity, the physical parameters of the brine, and the structural parameters, determining the first temperature field data of the brine in the central pipe; based on the second flow velocity and the physical parameters of the intermediate pipe, determining the second temperature field data of the brine in the annular space; and based on the first temperature field data and the second temperature field data, determining the temperature field data of the brine in the wellbore.

[0141] In a possible implementation, the first flow velocity satisfies a first preset formula, and the second flow velocity satisfies a second preset formula. The first preset formula is:

[0142]

[0143] where v bi represents the flow velocity of the brine in the central pipe, S represents the cavity-forming displacement, and the cavity-forming displacement refers to the volume of fluid injected into or discharged from the wellbore per unit time. r in represents the inner radius of the central pipe. The second preset formula is:

[0144]

[0145] where v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, S represents the cavity-forming displacement; r in represents the inner radius of the central pipe, and r mi represents the inner radius of the intermediate pipe.

[0146] In a possible implementation, the first temperature field data satisfies a third preset formula. The third preset formula is:

[0147]

[0148] where T in represents the temperature of the brine in the central pipe, t represents the cavity-forming operation time, v bi represents the flow velocity of the brine in the central pipe, z represents the depth of the temperature measurement point, U in represents the heat transfer coefficient of the central pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, A in represents the cross-sectional area of the central pipe, and T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe.

[0149] In a possible implementation manner, the second temperature field data satisfies a fourth preset formula, and the fourth preset formula is:

[0150]

[0151] wherein, T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe, t represents the cavity-forming operation time, v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, z represents the depth of the temperature measurement point, T in represents the temperature of the brine in the central pipe, T e represents the formation temperature, and A and B are coefficients;

[0152] The coefficients A and B satisfy a fifth preset formula, and the fifth preset formula is:

[0153]

[0154] wherein, r in represents the inner radius of the central pipe, r mi represents the inner radius of the intermediate pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, U in represents the heat transfer coefficient of the central pipe, U mi represents the heat transfer coefficient of the intermediate pipe, A mi represents the cross-sectional area of the annular space between the intermediate pipe and the central pipe.

[0155] In a possible implementation manner, the determining module 402 determines the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine, including: determining the velocity distribution of the brine in the cavity of the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine; and determining the temperature field data of the brine in the salt cavern gas storage according to the velocity distribution and the physical parameters of the brine.

[0156] In a possible implementation manner, the velocity distribution of the brine in the cavity of the target salt cavern gas storage satisfies a sixth preset formula, and the sixth preset formula is:

[0157]

[0158] wherein, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the cavity-forming operation time, p represents the brine pressure, μ represents the viscosity of the brine, I represents the unit matrix, and F represents the external force applied to the brine.

[0159] In a possible implementation, the temperature field data of the brine in the salt cavern gas storage satisfies the seventh preset formula, and the seventh preset formula is:

[0160]

[0161] where T b represents the temperature of the brine in the cavity, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, k b represents the thermal conductivity of the brine, and Q b represents the comprehensive heat transfer rate between the brine and the surrounding rock wall.

[0162] The above is only the specific implementation manner of the present application, but the protection scope of the present application is not limited thereto. Any person skilled in the art within the technical scope disclosed by the present application can easily think of changes or substitutions, which should all be covered within the protection scope of the present application. Therefore, the protection scope of the present application shall be subject to the protection scope of the claims.

Claims

1. A method for determining temperature field data, characterized in that The method includes: Obtaining the structural parameters of the wellbore provided in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage; Based on the structural parameters and the physical parameters of the brine, determining the temperature field data of the brine in the wellbore; the temperature field data of the brine in the wellbore includes the temperatures of the brine at multiple positions in the wellbore; According to the temperature field data of the wellbore and the physical parameters of the brine, determining the temperature field data of the brine in the target salt cavern gas storage.

2. The method according to claim 1, wherein The wellbore is further provided with an intermediate pipe and a central pipe, and the determining the temperature field data of the wellbore based on the structural parameters and the physical parameters of the brine includes: According to the structural parameters, determining the first flow velocity of the brine in the central pipe and the second flow velocity in the annular space between the intermediate pipe and the central pipe; Based on the first flow velocity, the physical parameters of the brine, and the structural parameters, determining the first temperature field data of the brine in the central pipe; Based on the second flow velocity and the physical parameters of the intermediate pipe, determining the second temperature field data of the brine in the annular space; Based on the first temperature field data and the second temperature field data, determining the temperature field data of the brine in the wellbore.

3. The method according to claim 2, characterized in that, The first flow velocity satisfies a first preset formula, and the second flow velocity satisfies a second preset formula. The first preset formula is: Among them, v bi represents the flow velocity of the brine in the central pipe, S represents the cavity-forming displacement, and the cavity-forming displacement refers to the volume of fluid injected into or discharged from the wellbore per unit time; r in represents the inner radius of the central pipe, and the second preset formula is: wherein, v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, S represents the cavity-forming displacement, r in represents the inner radius of the central pipe, r mi represents the inner radius of the intermediate pipe.

4. The method according to claim 2, wherein The first temperature field data satisfies a third preset formula, and the third preset formula is: where, T in represents the temperature of the brine in the central pipe, t represents the operation time of cavity formation, v bi represents the flow velocity of the brine in the central pipe, z represents the depth of the temperature measurement point, U in represents the heat transfer coefficient of the central pipe, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, A in represents the cross-sectional area of the central pipe, T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe.

5. The method according to claim 2, characterized in that The second temperature field data satisfies a fourth preset formula, and the fourth preset formula is: Among them, T mi represents the temperature of the brine in the annular space between the intermediate pipe and the central pipe, t represents the operation time of cavity formation, and v bm represents the flow velocity of the brine in the annular space between the intermediate pipe and the central pipe, z represents the depth of the temperature measurement point, and T in represents the temperature of the brine in the central pipe, and T e represents the formation temperature, and A and B are coefficients; The coefficients A and B satisfy a fifth preset formula, and the fifth preset formula is: where r in represents the inner radius of the central tube, r mi represents the inner radius of the intermediate tube, C b represents the specific heat capacity of the brine, ρ b represents the density of the brine, U in represents the heat transfer coefficient of the central tube, U mi represents the heat transfer coefficient of the intermediate tube, A mi represents the cross-sectional area of the annular space between the intermediate tube and the central tube.

6. The method according to any one of claims 1 to 4, characterized in that According to the temperature field data of the wellbore and the physical parameters of the brine, determining the temperature field data of the brine in the target salt cavern gas storage includes: According to the temperature field data of the wellbore and the physical parameters of the brine, determining the velocity distribution of the brine in the cavity of the target salt cavern gas storage; According to the velocity distribution and the physical parameters of the brine, determining the temperature field data of the brine in the target salt cavern gas storage.

7. The method according to claim 5, wherein The velocity distribution of the brine in the cavity of the target salt cavern gas storage satisfies a sixth preset formula, and the sixth preset formula is: where ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, p represents the brine pressure, μ represents the viscosity of the brine, I represents the unit matrix, and F represents the external force applied to the brine.

8. The method according to claim 5, wherein The temperature field data of the brine in the target salt cavern gas storage satisfies a seventh preset formula, and the seventh preset formula is: Among them, T b represents the temperature of the brine in the cavity, ρ b represents the density of the brine, u represents the velocity distribution of the brine in the cavity, t represents the operation time of cavity formation, k b represents the thermal conductivity of the brine, Q b represents the heat exchange rate between the brine and the surrounding rock wall.

9. A device for determining temperature field data, characterized in that The pipeline construction time determination device includes: An acquisition module, configured to acquire the structural parameters of the wellbore provided in the target salt cavern gas storage and the physical parameters of the brine in the target salt cavern gas storage; A determination module, configured to determine the temperature field data of the brine in the wellbore based on the structural parameters and the physical parameters of the brine; The determination module is further configured to determine the temperature field data of the brine in the target salt cavern gas storage according to the temperature field data of the wellbore and the physical parameters of the brine.

10. An electronic device, characterized in that, It includes a memory and a processor; the memory and the processor are coupled; the memory is used to store instructions executable by the processor; when the processor executes the instructions, it executes the method for determining temperature field data according to any one of claims 1-8.

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