Method and system for calculating injection rate of hydrate inhibitor in deepwater oil and gas pipeline

Abstract

The invention provides a method and system for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline, and belongs to the technical field of flowing safety guarantee of deepwater pipelines. Calculating the phase equilibrium temperature and the supercooling degree corresponding to the node pressure on each node along the pipeline based on a hydrate phase equilibrium model; judging a hydrate generation risk based on the supercooling degree and determining a risk level; when the hydrate generation risk exists, the node with the maximum supercooling degree value in all the nodes is screened out, and the preparation dosage of the needed hydrate inhibitor is determined according to the node temperature, the node pressure and the phase equilibrium temperature of the node; and determining the required supplement dosage according to the risk level to which the node belongs, and taking the preparatory dosage and the supplement dosage as the injection amount of the hydrate inhibitor. According to the method, the hydrate risk condition can be accurately analyzed and alarmed through pipeline data, different doses are set according to different risks, and the injection amount of the hydrate inhibitor in the deepwater oil and gas pipeline is intelligently and reasonably regulated and controlled.

Description

Technical Field

[0001] The present invention belongs to the technical field of flow safety assurance of deepwater pipelines, and in particular relates to a method and system for calculating the injection amount of hydrate inhibitors in deepwater oil and gas pipelines. Background Art

[0002] The statements in this section merely provide background information related to the present invention and do not necessarily constitute prior art.

[0003] In deepwater long-distance pipelines under high pressure and low temperature, the formation of natural gas hydrates often poses a serious threat to pipeline transportation safety. Once hydrates are generated, if effective hydrate management measures are not taken in time, as hydrate deposition further develops, it may even cause pipeline blockage. Therefore, it is necessary to study a method that can effectively detect and inhibit hydrates in pipelines.

[0004] However, the existing methods for detecting and suppressing hydrates in deepwater oil and gas pipelines still have some technical problems, such as:

[0005] (1) At present, with the advancement of pipeline network calculation models and the installation of more data instruments, more and more field pipelines rely on pipeline prediction models or data collectors distributed along the pipeline nodes; however, the data collected by these data collectors are only used to evaluate the pipeline production conditions, attempting to reduce the formation of hydrates by improving the quality of the pipeline; however, this method can only delay but not eliminate the formation of hydrates.

[0006] (2) Currently, most pipelines prevent hydrate formation by injecting hydrate thermodynamic inhibitors. However, during pipeline operation, it is often difficult for on-site personnel to evaluate the hydrate risk and injection volume based on the current actual working conditions. At the same time, the amount of inhibitor injected needs to consider both the inhibition effect and the on-site cost. Excessive injection will lead to increased costs, while insufficient inhibition will lead to hydrate blockage in the pipeline. Therefore, this method cannot adjust the dosage of inhibitors according to the degree of hydrate formation, resulting in unsatisfactory protection of pipeline safety and high costs. Summary of the invention

[0007] In order to overcome the deficiencies of the above-mentioned prior art, the present invention provides a method and system for calculating the injection amount of hydrate inhibitor in deepwater oil and gas pipelines, which can use pipeline data to accurately analyze and alarm the hydrate risk situation, and set different dosages for different risks, thereby realizing intelligent and reasonable regulation of the injection amount of hydrate inhibitor in deepwater oil and gas pipelines.

[0008] To achieve the above objectives, one or more embodiments of the present invention provide the following technical solutions:

[0009] A first aspect of the present invention provides a method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline.

[0010] A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline comprises:

[0011] Acquire real-time data of each node along the deepwater oil and gas pipeline, wherein the real-time data includes node temperature and node pressure;

[0012] Based on the hydrate phase equilibrium model, the phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline is calculated, and the supercooling degree of each node is calculated based on the obtained phase equilibrium temperature and node temperature; based on the obtained supercooling degree, it is determined whether there is a risk of hydrate formation and the risk level is determined;

[0013] When it is determined that there is a risk of hydrate formation, the node with the largest supercooling value among all nodes along the deepwater oil and gas pipeline is screened out, and the required reserve dosage of hydrate inhibitor is determined based on the node temperature, node pressure and phase equilibrium temperature of the node; at the same time, the required supplementary dosage is determined according to the risk level of the node, and the obtained reserve dosage and supplementary dosage are used as the final required hydrate inhibitor injection amount.

[0014] Furthermore, a plurality of nodes are arranged at equal intervals along the deepwater oil and gas pipeline; wherein a data table is arranged at each node for detecting real-time data at the location of the node.

[0015] Furthermore, the hydrate phase equilibrium model is a Chen-Guo model for predicting hydrate phase equilibrium conditions.

[0016] Furthermore, the degree of subcooling of any node along the deepwater oil and gas pipeline is the difference between the phase equilibrium temperature corresponding to the node and the node temperature.

[0017] Furthermore, judging whether there is a risk of hydrate formation and determining the risk level based on the obtained supercooling degree includes: setting a supercooling threshold, comparing the value of the obtained supercooling degree with the value of the set supercooling threshold to judge whether there is a risk of hydrate formation and determine the risk level.

[0018] Furthermore, when the obtained supercooling value is negative, it is considered that there is no hydrate formation risk in the node area, that is, the risk level is a safe level; when the obtained supercooling value is between 0 and the supercooling threshold, it is considered that there is a hydrate formation risk in the node area but the risk is low, that is, the risk level is a low risk level; when the obtained supercooling value exceeds the supercooling threshold, it is considered that there is a hydrate formation risk in the node area and the risk is high, that is, the risk level is a high risk level.

[0019] Further, determine the required supplementary dose according to the risk level to which the node belongs, including: setting values x and y; where both values x and y are constants, and satisfy 5 < x ≤ y < 15; when the risk level to which the node belongs is the low-risk level, use x% of the obtained preliminary dose as the required supplementary dose; when the risk level to which the node belongs is the high-risk level, use y% of the obtained preliminary dose as the required supplementary dose.

[0020] The second aspect of the present invention provides a system for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline.

[0021] A system for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline, including:

[0022] A data acquisition module, configured to: obtain real-time data of each node along the deepwater oil and gas pipeline, where the real-time data includes the node temperature and the node pressure;

[0023] A risk level judgment module, configured to: calculate the phase equilibrium temperature corresponding to the node pressure of each node along the deepwater oil and gas pipeline based on the hydrate phase equilibrium model, and calculate the degree of subcooling of each node based on the obtained phase equilibrium temperature and the node temperature; judge whether there is a risk of hydrate formation based on the obtained degree of subcooling and determine the risk level;

[0024] An injection amount calculation module, configured to: when it is determined that there is a risk of hydrate formation, screen out the node with the largest degree of subcooling value among each node along the deepwater oil and gas pipeline, and determine the preliminary dose of the required hydrate inhibitor according to the node temperature, node pressure and phase equilibrium temperature of this node; at the same time, determine the required supplementary dose according to the risk level to which this node belongs, and use the obtained preliminary dose and supplementary dose as the final required injection amount of the hydrate inhibitor.

[0025] The third aspect of the present invention provides a computer-readable storage medium, on which a program is stored, and when the program is executed by a processor, it implements the steps in a method for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline as described in the first aspect of the present invention.

[0026] The fourth aspect of the present invention provides an electronic device, including a memory, a processor, and a program stored on the memory and executable on the processor. When the processor executes the program, it implements the steps in a method for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline as described in the first aspect of the present invention.

[0027] The above one or more technical solutions have the following beneficial effects:

[0028] (1) The present invention collects real-time data of each node along the deepwater oil and gas pipeline through a data table, and uses these data as a basis for calculation, thereby determining the supercooling of each node; and then judging whether there is a risk of hydrate formation in the node area based on the value of the supercooling. Therefore, the present invention can directly judge the formation of hydrates in the pipeline based on the collected data, instead of relying on the construction of pipeline production, and can more directly and efficiently prevent the formation of hydrates in the pipeline.

[0029] (2) The present invention calculates the degree of supercooling based on the real-time data collected from each node along the deepwater oil and gas pipeline. On this basis, the obtained degree of supercooling is used to determine whether there is a risk of hydrate formation and determine the risk level; according to different risk levels, it is selected whether to inject hydrate inhibitors into the pipeline and how much inhibitor to inject. Therefore, the present invention can set different dosages for different risks, realize intelligent and reasonable regulation of the injection amount of hydrate inhibitors in deepwater oil and gas pipelines, and prevent the formation of hydrates in the pipeline on the basis of reducing the cost of inhibitor dosage.

[0030] Advantages of additional aspects of the present invention will be given in part in the following description, and in part will become obvious from the following description, or will be learned through practice of the present invention. BRIEF DESCRIPTION OF THE DRAWINGS

[0031] The accompanying drawings in the specification, which constitute a part of the present invention, are used to provide a further understanding of the present invention. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute improper limitations on the present invention.

[0032] Figure 1 This is a flow chart of a method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline in Example 1 of the present invention. DETAILED DESCRIPTION

[0033] It should be noted that the following detailed descriptions are exemplary and are intended to provide further explanation of the present invention. Unless otherwise specified, all technical and scientific terms used herein have the same meanings as those commonly understood by those skilled in the art to which the present invention belongs.

[0034] It should be noted that the terms used herein are for describing specific embodiments only and are not intended to be limiting of exemplary embodiments according to the present invention.

[0035] In the absence of conflict, the embodiments of the present invention and the features of the embodiments may be combined with each other.

[0036] The overall idea proposed by the present invention is as follows: the present invention provides a method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline. The method relies on the real-time operating condition data along the pipeline of an online system. First, the hydrate phase equilibrium is calculated based on the pipeline operating condition. Then, the existence or non-existence of hydrate risk areas and the risk level to which they belong are divided according to the supercooling degree along the pipeline, and finally the optimal analysis and control of the injection amount of hydrate inhibitor in the pipeline are achieved.

[0037] Embodiment 1

[0038] This embodiment discloses a method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline.

[0039] like Figure 1 As shown, a method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline includes:

[0040] Step S1, acquiring real-time data of each node along the deepwater oil and gas pipeline, wherein the real-time data includes node temperature and node pressure;

[0041] Step S2, calculating the phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline based on the hydrate phase equilibrium model, and calculating the supercooling of each node based on the obtained phase equilibrium temperature and the node temperature; judging whether there is a hydrate formation risk based on the obtained supercooling and determining the risk level;

[0042] Step S3: When it is determined that there is a risk of hydrate formation, the node with the largest supercooling value among the nodes along the deepwater oil and gas pipeline is screened out, and the required reserve dosage of the hydrate inhibitor is determined according to the node temperature, node pressure and phase equilibrium temperature of the node; at the same time, the required supplementary dosage is determined according to the risk level of the node, and the obtained reserve dosage and supplementary dosage are used as the final required hydrate inhibitor injection amount.

[0043] Based on the above process, the present invention can use pipeline data to accurately analyze and alarm the hydrate risk situation, and set different doses for different risks, so as to realize intelligent and reasonable regulation of the injection amount of hydrate inhibitor in deepwater oil and gas pipelines. To facilitate the understanding of the technical solution of the present invention, the specific implementation steps in the technical solution of the present invention are further explained and illustrated below.

[0044] Step S1, obtaining real-time data of each node along the deepwater oil and gas pipeline; wherein the real-time data includes node temperature and node pressure.

[0045] A plurality of data tables for acquiring data are arranged along the deepwater oil and gas pipeline. Specifically, a plurality of nodes are arranged at equal intervals along the deepwater oil and gas pipeline; wherein, a data table is arranged at each node for detecting real-time data at the node location. In this embodiment, a node is divided every 10 m along the deepwater oil and gas pipeline, and the total number of nodes is recorded as m; the data table arranged at each node will send the node data at the corresponding position to the data processing terminal.

[0046] Furthermore, the real-time data that can be collected by the data table include data such as node temperature and node pressure at the node location; and in the actual operation process, the collected node temperature and node pressure are stored separately, that is, the real-time data obtained at each node along the deepwater oil and gas pipeline are grouped. Among them, the data table used can be an instrument that can arbitrarily detect the temperature and pressure at the current pipeline location, and this embodiment does not limit its specific form; of course, the data table used can be two instruments that measure temperature or pressure separately, or it can be a comprehensive measurement instrument that jointly measures temperature and pressure.

[0047] Furthermore, the source of real-time data on deepwater oil and gas pipelines can be real-time data obtained through direct measurement of data tables set up along the on-site pipelines, or it can be simulated data along the pipeline obtained through simulation calculations based on pipeline inlet and outlet measurement data; but it should be noted that no matter which form of data source is used, it is necessary to ensure the timeliness of the data when obtaining data along the deepwater oil and gas pipelines.

[0048] Step S2: Calculate the phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline based on the hydrate phase equilibrium model, calculate the supercooling of each node based on the obtained phase equilibrium temperature and node temperature; and determine whether there is a hydrate formation risk based on the obtained supercooling and determine the risk level.

[0049] First, the phase equilibrium temperature of each node along the deepwater oil and gas pipeline is calculated. The hydrate phase equilibrium model used in this embodiment is the Chen-Guo model for predicting hydrate phase equilibrium conditions. Specifically, the phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline is calculated based on the Chen-Guo model. Specifically: the Chen-Guo model is used for hydrate phase equilibrium calculation. The model avoids the calculation of chemical potential and simplifies the calculation process of hydrate formation conditions; the core idea of ​​the Chen-Guo model is that when the gas phase fugacity is equal to the solid phase fugacity, it can be considered that hydrate is generated, that is, the temperature and pressure conditions when the gas phase and solid phase fugacity are the same are the phase equilibrium temperature and pressure of the hydrate. It should be noted that the use of the Chen-Guo model has been relatively broad, and this embodiment selects the Chen-Guo model as a way to calculate the phase equilibrium temperature; the choice of the hydrate phase equilibrium model can be selected according to actual conditions. This embodiment does not restrict the modification of the specific calculation content of the model, as long as the calculation accuracy is guaranteed.

[0050] Subsequently, the degree of subcooling is calculated by performing difference processing between the hydrate phase equilibrium temperature of each node along the deepwater oil and gas pipeline and the real-time temperature of each node, including: calculating the degree of subcooling of each node along the deepwater oil and gas pipeline based on the obtained phase equilibrium temperature and the node temperature. Specifically, the degree of subcooling of any node along the deepwater oil and gas pipeline is the difference between the phase equilibrium temperature corresponding to the node and the node temperature, that is:

[0051] g=[g1,g2,...,g m ];

[0052] g i =d i -s i ;

[0053] Among them, g represents the supercooling degree of all nodes along the deepwater oil and gas pipeline, g i represents the degree of subcooling at the i-th node along the deepwater oil and gas pipeline, m represents the total number of nodes; d i represents the node temperature at the i-th node along the deepwater oil and gas pipeline, p i represents the phase equilibrium temperature at the i-th node along the deepwater oil and gas pipeline.

[0054] Next, based on the obtained supercooling, determine whether there is a risk of hydrate formation and determine the risk level. Specifically: set the supercooling threshold in, represents the overcooling threshold of all nodes along the deepwater oil and gas pipeline. It represents the supercooling threshold at the ith node along the deepwater oil and gas pipeline. The obtained supercooling value is compared with the set supercooling threshold to determine whether there is a risk of hydrate formation and determine the risk level.

[0055] Furthermore, when the value of the supercooling obtained at a node along the deepwater oil and gas pipeline is negative, it is considered that there is no risk of hydrate formation in the node area, that is, the risk level of the node area is a safe level; when the value of the supercooling obtained is between 0 and the supercooling threshold, it is considered that there is a risk of hydrate formation in the node area but the risk is low, that is, the risk level of the node area is a low risk level; when the value of the supercooling obtained exceeds the supercooling threshold, it is considered that there is a risk of hydrate formation in the node area and the risk is high, that is, the risk level of the node area is a high risk level.

[0056] Furthermore, in this embodiment, the supercooling threshold is set to 3k, where k is the temperature unit (Kelvin). Taking the i-th node along the deepwater oil and gas pipeline as an example: when g i <0, it means that there is no hydrate formation risk in the node area where the i-th node is located along the pipeline, and the risk level is safe; When , it means that there is a risk of hydrate formation in the node area where the i-th node is located along the pipeline, but the risk is low, and the risk level is low; when When , it means that there is a risk of hydrate formation in the node area where the i-th node is located along the pipeline, and the risk is relatively high, and the risk level is high risk level. It should be noted that the specific value of the supercooling threshold can be set according to actual needs. This embodiment only provides a preferred implementation method for this, and does not impose specific limitations on this.

[0057] Step S3: When it is determined that there is a risk of hydrate formation, the node with the largest supercooling value among the nodes along the deepwater oil and gas pipeline is screened out, and the required reserve dosage of the hydrate inhibitor is determined according to the node temperature, node pressure and phase equilibrium temperature of the node; at the same time, the required supplementary dosage is determined according to the risk level of the node, and the obtained reserve dosage and supplementary dosage are used as the final required hydrate inhibitor injection amount.

[0058] When it is determined that there is no hydrate formation risk in the node area at any node along the deepwater oil and gas pipeline, hydrate inhibitors are not injected into the deepwater oil and gas pipeline. When it is determined that there is a hydrate formation risk in the node area at any node along the deepwater oil and gas pipeline, supercooling screening is performed, that is, the node with the largest supercooling value among the nodes along the deepwater oil and gas pipeline is screened, and the node is used as the injection node for the preparation of hydrate inhibitor injection; at the same time, the node pressure, node temperature and phase equilibrium temperature corresponding to the node are read, and the phase equilibrium temperature corresponding to the node pressure is used to reversely deduce the preparation dose of hydrate inhibitor to be injected, that is: the hydrate phase equilibrium formula containing inhibitors is used to calculate the amount of inhibitor that needs to be injected under the current supercooling conditions (this required injection amount is the preparation dose) to make the hydrate phase equilibrium temperature under the node pressure condition lower than the real-time temperature, and the obtained preparation dose is used as the minimum injection dose required for injection into the node. It should be noted that the reason for choosing the node with the largest degree of supercooling is that as long as the risk of hydrate formation is no longer present at this node, the hydrate hazard of the entire deepwater oil and gas pipeline will disappear. In addition, the phase equilibrium temperature corresponding to the pressure at this node is used to infer the required preparation dose of the hydrate inhibitor to be injected. In essence, it is still the calculation of phase equilibrium using the Chen-Guo model. However, it is necessary to add a water activity calculation model on this basis, and to calculate the hydrate injection dose through the coupling calculation method of these two models.

[0059] Furthermore, considering the safety of the pipeline, it is necessary to add a certain amount of supplementary dose on the basis of the minimum injection dose (preliminary dose), and use the obtained preliminary dose and supplementary dose as the final required hydrate inhibitor injection amount to ensure that no hydrate will be generated under the current operating conditions.

[0060] Furthermore, in order to control the injection cost of the hydrate inhibitor while ensuring that no hydrate is generated under the current operating conditions, this embodiment selects to determine the required supplementary dosage according to the risk level of the injection node, specifically:

[0061] Set the numerical values of x and y; where both the numerical values of x and y are constants, and satisfy 5 < x ≤ y < 15. When the risk level to which the node belongs is the low-risk level, x% of the obtained preliminary dose is used as the required supplementary dose; when the risk level to which the node belongs is the high-risk level, y% of the obtained preliminary dose is used as the required supplementary dose. Preferably, in this embodiment, the numerical value of x = 10 and y = 12. Assuming that the preliminary dose of the injection node is A, then: when the risk level to which the injection node belongs is the low-risk level, 10% of the obtained preliminary dose is used as the required supplementary dose, and at this time, the injection amount of the hydrate inhibitor to be injected into the injection node is A + A * 10%; when the risk level to which the injection node belongs is the high-risk level, 12% of the obtained preliminary dose is used as the required supplementary dose, and at this time, the injection amount of the hydrate inhibitor to be injected into the injection node is A + A * 12%. It can be understood that the specific numerical values of the constants x and y can be set according to the actual situation, and this embodiment does not make specific restrictions on this either.

[0062] Based on the above method of the present invention, it is possible to accurately analyze and alarm the hydrate risk situation by using pipeline data, and set different doses for different risks, so as to realize the intelligent and reasonable regulation of the injection amount of hydrate inhibitors in deep-water oil and gas pipelines.

[0063] Embodiment 2

[0064] This embodiment discloses a calculation system for the injection amount of hydrate inhibitors in deep-water oil and gas pipelines.

[0065] A calculation system for the injection amount of hydrate inhibitors in deep-water oil and gas pipelines, comprising:

[0066] A data acquisition module, configured to: obtain real-time data of each node along the deep-water oil and gas pipeline, and the real-time data includes node temperature and node pressure;

[0067] A risk level judgment module, configured to: calculate the phase equilibrium temperature corresponding to the node pressure of each node along the deep-water oil and gas pipeline based on the hydrate phase equilibrium model, and calculate the subcooling degree of each node based on the obtained phase equilibrium temperature and node temperature; judge whether there is a risk of hydrate formation based on the obtained subcooling degree and determine the risk level;

[0068] An injection amount calculation module, configured to: when it is determined that there is a risk of hydrate formation, screen out the node with the largest subcooling degree value among each node along the deep-water oil and gas pipeline, and determine the preliminary dose of the required hydrate inhibitor according to the node temperature, node pressure and phase equilibrium temperature of this node; at the same time, determine the required supplementary dose according to the risk level to which this node belongs, and use the obtained preliminary dose and supplementary dose as the final required injection amount of the hydrate inhibitor.

[0069] Embodiment 3

[0070] The purpose of this embodiment is to provide a computer-readable storage medium.

[0071] A computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps in a method for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline as described in the first embodiment of the present disclosure.

[0072] Embodiment 4

[0073] The purpose of this embodiment is to provide an electronic device.

[0074] An electronic device includes a memory, a processor, and a program stored in the memory and executable on the processor. When the processor executes the program, the steps in the method for calculating the injection amount of a hydrate inhibitor in a deepwater oil and gas pipeline as described in the first embodiment of the present disclosure are implemented.

[0075] The steps involved in the apparatuses of the above embodiments 2, 3 and 4 correspond to the method embodiment 1, and the specific implementation methods can refer to the relevant description part of embodiment 1. The term "computer-readable storage medium" should be understood as a single medium or multiple media including one or more instruction sets; it should also be understood to include any medium that can store, encode or carry an instruction set for execution by a processor and enable the processor to execute any method in the present invention.

[0076] Those skilled in the art should understand that the modules or steps of the present invention described above can be implemented by a general-purpose computer device, or alternatively, they can be implemented by a program code executable by a computing device, so that they can be stored in a storage device and executed by the computing device, or they can be made into individual integrated circuit modules, or multiple modules or steps therein can be made into a single integrated circuit module for implementation. The present invention is not limited to any specific combination of hardware and software.

[0077] Although the above describes the specific implementation mode of the present invention in conjunction with the accompanying drawings, it is not intended to limit the scope of protection of the present invention. Those skilled in the art should understand that various modifications or variations that can be made by those skilled in the art on the basis of the technical solution of the present invention without creative work are still within the scope of protection of the present invention.

Claims

1. A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline, characterized in that: include: Acquire real-time data of each node along the deepwater oil and gas pipeline, wherein the real-time data includes node temperature and node pressure; The phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline is calculated based on the hydrate phase equilibrium model, and the subcooling degree of each node is calculated based on the obtained phase equilibrium temperature and node temperature; Based on the obtained undercooling, it is judged whether there is a risk of hydrate formation and the risk level is determined; When it is determined that there is a risk of hydrate formation, the node with the largest supercooling value among all nodes along the deepwater oil and gas pipeline is screened out, and the required reserve dosage of hydrate inhibitor is determined based on the node temperature, node pressure and phase equilibrium temperature of the node; at the same time, the required supplementary dosage is determined according to the risk level of the node, and the obtained reserve dosage and supplementary dosage are used as the final required hydrate inhibitor injection amount.

2. A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 1, characterized in that: A plurality of nodes are arranged at equal intervals along the deepwater oil and gas pipeline; wherein a data table is arranged on each node for detecting real-time data at the location of the node.

3. The method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 1, characterized in that: The hydrate phase equilibrium model is the Chen-Guo model used to predict hydrate phase equilibrium conditions.

4. A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 1, characterized in that: The degree of subcooling at any node along the deepwater oil and gas pipeline is the difference between the phase equilibrium temperature corresponding to the node and the node temperature.

5. The method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 1, characterized in that: Based on the obtained supercooling degree, judging whether there is a risk of hydrate formation and determining the risk level includes: setting a supercooling threshold, comparing the value of the obtained supercooling degree with the value of the set supercooling threshold to judge whether there is a risk of hydrate formation and determining the risk level.

6. A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 5, characterized in that: When the obtained supercooling value is negative, it is considered that there is no hydrate formation risk in the node area, that is, the risk level is safe level; when the obtained supercooling value is between 0 and the supercooling threshold, it is considered that there is a hydrate formation risk in the node area but the risk is low, that is, the risk level is low risk level; when the obtained supercooling value exceeds the supercooling threshold, it is considered that there is a hydrate formation risk in the node area and the risk is high, that is, the risk level is high risk level.

7. A method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline according to claim 1, characterized in that: Determine the required supplementary dose according to the risk level of the node, including: setting values ​​x and y; where values ​​x and y are both constants and meet 5 <x≤y<15; When the risk level of the node is low, x% of the prepared dose is used as the required supplementary dose; when the risk level of the node is high, y% of the prepared dose is used as the required supplementary dose.

8. A system for calculating the amount of hydrate inhibitor injected into a deepwater oil and gas pipeline, characterized in that: include: The data acquisition module is configured to: obtain real-time data of each node along the deepwater oil and gas pipeline, wherein the real-time data includes node temperature and node pressure; The risk level judgment module is configured to: calculate the phase equilibrium temperature corresponding to the node pressure at each node along the deepwater oil and gas pipeline based on the hydrate phase equilibrium model, and calculate the undercooling degree of each node based on the obtained phase equilibrium temperature and the node temperature; Based on the obtained undercooling, it is judged whether there is a risk of hydrate formation and the risk level is determined; The injection amount calculation module is configured as follows: when it is determined that there is a risk of hydrate formation, the node with the largest supercooling value among the nodes along the deepwater oil and gas pipeline is screened out, and the required reserve dosage of the hydrate inhibitor is determined according to the node temperature, node pressure and phase equilibrium temperature of the node; at the same time, the required supplementary dosage is determined according to the risk level of the node, and the obtained reserve dosage and supplementary dosage are used as the final required hydrate inhibitor injection amount.

9. A computer-readable storage medium having a program stored thereon, characterized in that: When the program is executed by a processor, the steps of the method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline as described in any one of claims 1 to 7 are implemented.

10. An electronic device comprising a memory, a processor, and a program stored in the memory and executable on the processor, characterized in that: When the processor executes the program, the steps in the method for calculating the injection amount of hydrate inhibitor in a deepwater oil and gas pipeline as described in any one of claims 1 to 7 are implemented.

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