A method and system for evaluating the status of an oil and gas pipeline network

Abstract

The present invention discloses a method and system for assessing the status of an oil and gas pipeline network, relating to the technical field of oil and gas pipeline networks. The method comprises: obtaining and assessing the blockage degree of the multiphase flow pipeline to be assessed in the oil and gas pipeline network based on the inlet and outlet flow rates of the multiphase flow pipeline to be assessed; obtaining and assessing the corrosion degree of the multiphase flow pipeline to be assessed based on the real-time wall thickness of the multiphase flow pipeline to be assessed; obtaining and predicting the density of the fluid in the multiphase flow pipeline to be assessed based on the real-time temperature of the environment in which the multiphase flow pipeline to be assessed is used to estimate the metal fatigue degree of the multiphase flow pipeline to be assessed based on the density of the fluid; and assessing the network status of the multiphase flow pipeline to be assessed based on the blockage degree, corrosion degree, and metal fatigue degree of the multiphase flow pipeline to be assessed. The present invention can automatically assess the network status of an oil and gas pipeline network, reduce the manual workload, and improve assessment efficiency and accuracy.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas pipeline networks, and in particular to a state assessment method and system for an oil and gas pipeline network. Background Art

[0002] Oil and gas pipeline networks are a vital component of modern energy systems, and ensuring their safe and stable operation is crucial. However, due to the inherent complexity of oil and gas pipeline networks and the diverse environments they operate in, comprehensive and accurate assessment of their condition is challenging. To address this issue, oil and gas pipeline network condition assessment has emerged.

[0003] Oil and gas pipeline network condition assessment is a technology based on data analysis and model prediction. It collects, processes, and analyzes pipeline system operational data to quickly understand the pipeline system's condition. The value of oil and gas pipeline network condition assessment lies not only in timely identification of problems but also in helping system managers take appropriate countermeasures.

[0004] Oil and gas pipeline network condition assessments not only ensure the safe and stable operation of pipeline systems, but also contribute to energy conservation and environmental protection. By promptly identifying and resolving potential safety hazards, oil and gas pipeline network condition assessments can reduce accidents and minimize energy losses. Furthermore, by optimizing pipeline system operations, oil and gas pipeline network condition assessments can improve energy efficiency and reduce environmental impact.

[0005] In short, oil and gas pipeline network status assessment is an indispensable part of the modern energy system. Therefore, it is of great significance to invent a pipeline network status assessment method for multiphase flow pipeline networks. Summary of the Invention

[0006] The technical problem to be solved by the present invention is to address the deficiencies of the existing technology and specifically provide a method and system for evaluating the status of an oil and gas pipeline network, as follows:

[0007] 1) In a first aspect, the present invention provides a method for evaluating the status of an oil and gas pipeline network. The specific technical solution is as follows:

[0008] Obtaining and evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network;

[0009] Obtain and evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated;

[0010] Obtain and predict the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimate the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid;

[0011] The network status of the multiphase flow pipeline to be evaluated is evaluated based on the blockage degree, corrosion degree and metal fatigue degree of the multiphase flow pipeline to be evaluated.

[0012] The beneficial effects of the oil and gas pipeline network status assessment method provided by the present invention are as follows:

[0013] By assessing the status of oil and gas pipeline networks, the present invention can promptly detect pipeline anomalies, such as blockages and corrosion, enabling targeted repairs and replacements, reducing repair costs and downtime, and improving the convenience and efficiency of pipeline maintenance. By employing intelligent technology for data acquisition, processing, and analysis, the present invention can automatically assess the status of oil and gas pipeline networks, reducing manual workload and improving assessment efficiency and accuracy. Furthermore, the present invention can obtain flow rate data at the inlet and outlet of the multiphase flow pipeline to be assessed, real-time pipe wall thickness, and real-time temperature data of the surrounding environment, thereby providing a comprehensive understanding of the pipeline's performance and safety.

[0014] 2) In a second aspect, the present invention further provides a state assessment system for an oil and gas pipeline network, the specific technical solution of which is as follows: comprising a fluid flow detection unit, a pipe wall thickness detection unit, a temperature detection unit, and a data analysis unit;

[0015] The fluid flow detection unit is used to: obtain the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network;

[0016] The pipe wall thickness detection unit is used to: obtain the real-time pipe wall thickness of the multiphase flow pipeline to be evaluated;

[0017] The temperature detection unit is used to: obtain the real-time temperature of the multiphase flow pipeline to be evaluated;

[0018] The data analysis unit is used to: evaluate the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated; evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated; predict the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimate the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid; and evaluate the pipeline network status of the multiphase flow pipeline to be evaluated based on the blockage degree, corrosion degree and metal fatigue degree of the multiphase flow pipeline to be evaluated.

[0019] 3) In a third aspect, the present invention further provides a computer device, comprising a processor coupled to a memory, wherein the memory stores at least one computer program, and the at least one computer program is loaded and executed by the processor so that the computer device implements any of the above-mentioned oil and gas pipeline network status assessment methods.

[0020] 4) In a fourth aspect, the present invention further provides a computer-readable storage medium, in which at least one computer program is stored, and the at least one computer program is loaded and executed by a processor so that the computer implements any of the above-mentioned oil and gas pipeline network status assessment methods.

[0021] It should be noted that the beneficial effects achieved by the technical solutions of the second to fourth aspects of the present invention and the corresponding possible implementation methods can be found in the above-mentioned technical effects of the first aspect and its corresponding possible implementation methods, and will not be repeated here. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] Other features, objects and advantages of the present invention will become more apparent upon reading the detailed description of non-limiting embodiments made with reference to the following drawings:

[0023] Figure 1 Schematic diagram of a flow chart of a method for evaluating the state of an oil and gas pipeline network according to an embodiment of the present invention;

[0024] Figure 2 This is a schematic structural diagram of a system for evaluating the status of an oil and gas pipeline network according to an embodiment of the present invention;

[0025] Figure 3 The figure is a structural diagram of a computer device according to an embodiment of the present invention. DETAILED DESCRIPTION

[0026] To make the objectives, technical solutions and advantages of the present invention more clear, the embodiments of the present invention will be described in further detail below with reference to the accompanying drawings.

[0027] like Figure 1 As shown, a method for evaluating the status of an oil and gas pipeline network according to an embodiment of the present invention includes the following steps:

[0028] S1. Obtain and evaluate the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network;

[0029] S2. Obtain and evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated;

[0030] S3. Obtaining and predicting the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimating the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid;

[0031] S4. Evaluate the network status of the multiphase flow pipeline to be evaluated based on the blockage degree, corrosion degree, and metal fatigue degree of the multiphase flow pipeline to be evaluated.

[0032] The oil and gas pipeline network is a multiphase flow pipeline network composed of a number of multiphase flow pipelines. The multiphase flow pipeline network is connected to an oil and gas separation station, which is used to receive the fluid in the phase flow pipeline.

[0033] Optionally, in S1, evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and the outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network includes:

[0034] S10, calculating the flow difference and flow ratio between the inlet flow rate and the outlet flow rate, the flow difference calculation formula is: ΔF = F0-F1, the flow ratio calculation formula is: Fx = F0 / F1, where ΔF represents the flow difference, F0 represents the inlet flow rate, F1 represents the outlet flow rate, and Fx represents the flow ratio;

[0035] S11. Calculate the flow quotient of the flow difference and the flow ratio. The flow quotient calculation formula is: Fy = ΔF / Fx, where Fy represents the flow quotient;

[0036] S12. Preset a preset flow quotient value, compare the flow quotient value with the preset flow quotient value, and evaluate the blockage degree of the multiphase flow pipeline to be evaluated based on the comparison result.

[0037] Optionally, in S12, comparing the flow quotient value with a preset flow quotient value, and evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the comparison result, includes:

[0038] S120, when the flow quotient value is less than the preset flow quotient value, it is determined that the multiphase flow pipeline to be evaluated is not blocked, and the blockage degree of the multiphase flow pipeline to be evaluated is 0;

[0039] S121. When the flow quotient value is not less than a preset flow quotient value, determine that the multiphase flow pipeline to be evaluated is blocked, and calculate the flow quotient difference between the flow quotient value and the preset flow quotient value;

[0040] S122: A first preset flow quotient difference value and a second preset flow quotient difference value are preset, and the first preset flow quotient difference value is smaller than the second preset flow quotient difference value, then:

[0041] 1) When the flow quotient difference is less than a first preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as slight blockage;

[0042] 2) When the flow quotient difference is not less than the first preset flow quotient difference and less than the second preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as moderate blockage;

[0043] 3) When the flow quotient difference is not less than the second preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as severe blockage.

[0044] Optionally, in S2, evaluating the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated includes:

[0045] S20. Preset a preset pipe wall thickness and divide the multiphase flow pipeline to be evaluated into n segments on average to obtain n multiphase flow pipeline segments. S21. Evaluate the corrosion degree of each multiphase flow pipeline segment using the preset pipe wall thickness and the real-time pipe wall thickness of each multiphase flow pipeline segment. Evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the corrosion degree evaluation results of all multiphase flow pipeline segments.

[0046] Optionally, the corrosion level of any multiphase flow pipeline section can be evaluated, including:

[0047] S210, obtaining the pipe wall thicknesses at a plurality of points in any multiphase flow pipeline segment, calculating an average of the pipe wall thicknesses at the plurality of points, and using the average as the real-time pipe wall thickness of any multiphase flow pipeline segment;

[0048] S211. Calculate the thickness ratio between the average value and the preset thickness of the pipe wall. The thickness ratio is calculated using the formula: T = t / T0, where T represents the thickness ratio, t represents the average value, and T0 represents the preset thickness of the pipe wall. Then:

[0049] 1) When T is less than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is corroded;

[0050] 2) When T is equal to 1, the corrosion degree evaluation result of any multiphase flow pipeline section is not corroded;

[0051] 3) When T is greater than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is that there is deposit.

[0052] Optionally, in S21, the corrosion degree of the multiphase flow pipeline to be evaluated is evaluated based on the corrosion degree evaluation results of all multiphase flow pipeline sections, including:

[0053] S212: Preset a first corrosion preset number and a second corrosion preset number, and the first corrosion preset number is smaller than the second corrosion preset number. Obtain the number m of all multiphase flow pipeline segments where T is smaller than 1. Then:

[0054] 1) When m is less than the first corrosion preset number and greater than 0, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as mild corrosion;

[0055] 2) When m is greater than the first corrosion preset number and less than the second corrosion preset number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as moderate corrosion;

[0056] 3) When m is greater than the second preset corrosion number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as severe corrosion.

[0057] Optionally, the fluid in the multiphase flow pipeline to be evaluated is a mixed fluid of crude oil and natural gas. Obtaining and predicting the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is performed includes:

[0058] S30, obtaining the real-time temperature and the pressure in the multiphase flow pipeline to be evaluated, and predicting the density of the mixed fluid according to the density calculation formula. The density calculation formula is: Where ρ is the density of the mixed fluid, P is the pressure, R is the gas constant, T is the real-time temperature, and B is the Debye constant.

[0059] Optionally, the metal fatigue degree of the multiphase flow pipeline to be evaluated is estimated based on the density of the fluid, including:

[0060] S31. Calculate the stress amplitude of the multiphase flow pipeline to be evaluated under the conditions of the real-time temperature and the density of the mixed fluid using an empirical model, and calculate the fatigue life of the multiphase flow pipeline to be evaluated using the relationship between the stress amplitude and fatigue life in the SN curve;

[0061] S32. Preset a preset fatigue life, calculate the difference between the preset fatigue life and the fatigue life of the multiphase flow pipeline to be evaluated, and obtain a fatigue life margin. Then:

[0062] 1) Presetting a first fatigue life preset margin and a second fatigue life preset margin, wherein the first fatigue life preset margin is smaller than the second fatigue life preset margin;

[0063] 2) When the fatigue life margin is greater than the second fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue;

[0064] 3) When the fatigue life margin is not greater than the second fatigue life preset margin and greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue;

[0065] 4) When the fatigue life margin is not greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue.

[0066] It is understandable that the specific empirical model involves the following aspects:

[0067] Material properties: The model needs to consider the mechanical properties of the pipeline material, such as elastic modulus, yield strength, elongation, etc., in order to determine the behavior of the material under different stresses.

[0068] Temperature effect: Since changes in pipeline temperature will affect the mechanical properties of the material, the model will consider the effect of temperature on the strength and toughness of the material, usually using a temperature correction coefficient or considering the temperature dependence of the material.

[0069] Stress analysis: The model performs stress analysis, taking into account the stress state of the pipeline under various loads such as internal pressure, external pressure, temperature gradient, etc., and calculates the stress amplitude under real-time conditions.

[0070] Fatigue life prediction: Based on the SN curve, the real-time stress amplitude is matched with the fatigue performance curve of the pipeline material to estimate the fatigue life of the pipeline under real-time conditions.

[0071] The SN curve is a relationship between stress and fatigue life (number of cycles). This curve is derived from a large amount of experimental data and represents the fatigue life of a material under different stress levels.

[0072] Optionally, in S4, evaluating the network status of the multiphase flow pipeline to be evaluated according to the blockage degree, corrosion degree, and metal fatigue degree of the multiphase flow pipeline to be evaluated includes:

[0073] Scoring the multiphase flow pipeline to be assessed according to its blockage, corrosion and fatigue levels, and evaluating the network status of the multiphase flow pipeline to be assessed based on the scoring results;

[0074] Obtain a blockage score according to the blockage degree of the multiphase flow pipeline to be evaluated. When the blockage degree of the multiphase flow pipeline to be evaluated is light blockage, the blockage score is 1; when the blockage degree of the multiphase flow pipeline to be evaluated is moderate blockage, the blockage score is 2; when the blockage degree of the multiphase flow pipeline to be evaluated is severe blockage, the blockage score is 3;

[0075] A corrosion score is obtained according to the corrosion degree of the multiphase flow pipeline to be evaluated. When the corrosion degree of the multiphase flow pipeline to be evaluated is mild corrosion, the corrosion score is 1; when the corrosion degree of the multiphase flow pipeline to be evaluated is moderate corrosion, the corrosion score is 2; when the corrosion degree of the multiphase flow pipeline to be evaluated is severe corrosion, the corrosion score is 3;

[0076] A fatigue score is obtained according to the metal fatigue degree of the multiphase flow pipeline to be evaluated. When the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue, the fatigue score is 1; when the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue, the fatigue score is 2; when the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue, the fatigue score is 3;

[0077] The scoring result is the sum of the blockage score, corrosion score and fatigue score;

[0078] Presetting a first summed preset value and a second summed preset value;

[0079] When the sum value is less than the first sum preset value, the evaluation result of the pipe network state of the multiphase flow pipeline to be evaluated is a normal state;

[0080] When the sum value is not less than the first sum preset value and less than the second sum preset value, the evaluation result of the pipe network state of the multiphase flow pipeline to be evaluated is a warning state;

[0081] When the sum value is not less than the second sum preset value, the evaluation result of the pipeline network state of the multiphase flow pipeline to be evaluated is a fault state.

[0082] Optionally, in the above technical solution, each multiphase flow pipeline in the oil and gas pipeline network is used as a multiphase flow pipeline to be evaluated, and S1 to S4 are executed for each multiphase flow pipeline to obtain the pipeline network status of each multiphase flow pipeline in each oil and gas pipeline network.

[0083] The present invention can monitor oil and gas pipeline networks in real time, promptly acquiring data such as pipeline flow, pipe wall thickness, and ambient temperature, thereby enabling rapid assessment of pipeline blockage, corrosion, and metal fatigue, effectively preventing pipeline failures and accidents. By assessing the network status of the oil and gas pipeline network, potential safety hazards can be promptly discovered and resolved, effectively reducing the incidence of accidents such as pipeline leakage and explosion, and improving the safety and reliability of the oil and gas pipeline network. By performing status assessments on the oil and gas pipeline network, pipeline anomalies such as blockage and corrosion can be promptly discovered, enabling targeted repair and replacement, reducing repair costs and downtime, and improving the convenience and efficiency of pipeline maintenance. The method can predict fluid density based on the acquired ambient temperature and estimate the metal fatigue level of the pipeline based on the fluid density, thereby enabling early prediction of the pipeline's service life and replacement cycle, avoiding the waste and insecurity caused by premature pipeline damage or delayed replacement. The method utilizes intelligent technology for data acquisition, processing, and analysis, enabling automatic assessment of the network status of the oil and gas pipeline network, reducing manual workload and improving assessment efficiency and accuracy.

[0084] In the above embodiments, although the steps are numbered S1, S2, etc., these are only specific embodiments given by the present invention. Those skilled in the art may adjust the execution order of S1, S2, etc. according to actual conditions, which is also within the scope of protection of the present invention. It can be understood that in some embodiments, some or all of the above embodiments may be included.

[0085] like Figure 2 As shown, a state assessment system for an oil and gas pipeline network according to an embodiment of the present invention includes a fluid flow detection unit 201, a pipe wall thickness detection unit 202, a temperature detection unit 203 and a data analysis unit 204;

[0086] The fluid flow detection unit 201 is used to obtain the inlet flow and outlet flow of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network; the pipe wall thickness detection unit 202 is used to obtain the real-time pipe wall thickness of the multiphase flow pipeline to be evaluated;

[0087] The temperature detection unit 203 is used to: obtain the real-time temperature of the multiphase flow pipeline to be evaluated;

[0088] The data analysis unit 204 is used to: evaluate the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated; evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated; predict the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimate the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid; and evaluate the pipeline network status of the multiphase flow pipeline to be evaluated based on the blockage degree, corrosion degree and metal fatigue degree of the multiphase flow pipeline to be evaluated.

[0089] Preferably, the fluid flow detection unit 201 , the pipe wall thickness detection unit 202 and the temperature detection unit 203 are specifically a flow sensor, an ultrasonic thickness gauge and a temperature sensor, respectively.

[0090] Flow sensors are installed at the inlet and outlet of oil and gas pipelines to accurately measure flow changes in multiphase pipelines. This data is an important basis for assessing the degree of pipeline blockage.

[0091] Ultrasonic thickness gauges are used to measure the wall thickness of multiphase flow pipelines in real time. Regular or continuous measurements can promptly detect corrosion, wear, or thickness changes in the pipe wall, thereby assessing the extent of pipeline corrosion.

[0092] Temperature sensors are placed in the environment surrounding the multiphase flow pipeline to be evaluated, monitoring the temperature of the environment in real time. Since the density of a fluid changes with temperature, the density of the fluid in the pipeline can be predicted by measuring the ambient temperature.

[0093] Optionally, in the above technical solution, the data parsing unit 204 includes a congestion level assessment subunit, which is configured to:

[0094] Calculate the flow difference and flow ratio between the inlet flow and the outlet flow. The flow difference is calculated as: ΔF = F0 - F1, and the flow ratio is calculated as: Fx = F0 / F1, where ΔF represents the flow difference, F0 represents the inlet flow, F1 represents the outlet flow, and Fx represents the flow ratio.

[0095] Calculate the flow quotient of the flow difference and the flow ratio. The flow quotient calculation formula is: Fy = ΔF / Fx, where Fy represents the flow quotient;

[0096] A preset flow quotient value is set in advance, the flow quotient value is compared with the preset flow quotient value, and the blockage degree of the multiphase flow pipeline to be evaluated is evaluated based on the comparison result.

[0097] Optionally, in the above technical solution, the blockage degree assessment subunit is further specifically used to:

[0098] When the flow quotient value is less than the preset flow quotient value, it is determined that the multiphase flow pipeline to be evaluated is not blocked, and the blockage degree of the multiphase flow pipeline to be evaluated is 0;

[0099] When the flow quotient value is not less than the preset flow quotient value, it is determined that the multiphase flow pipeline to be evaluated is blocked, and the flow quotient difference between the flow quotient value and the preset flow quotient value is calculated;

[0100] A first preset flow quotient difference value and a second preset flow quotient difference value are preset, and the first preset flow quotient difference value is smaller than the second preset flow quotient difference value;

[0101] When the flow quotient difference is less than the first preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as mild blockage; when the flow quotient difference is not less than the first preset flow quotient difference and less than the second preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as moderate blockage;

[0102] When the flow quotient difference is not less than the second preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as severe blockage.

[0103] Optionally, in the above technical solution, the data analysis unit 204 further includes a corrosion degree assessment subunit, which is configured to:

[0104] The preset thickness of the pipe wall is pre-set, and the multiphase flow pipe to be evaluated is evenly divided into n sections to obtain n multiphase flow pipe sections;

[0105] The corrosion degree of each multiphase flow pipeline segment is evaluated by the preset pipe wall thickness and the real-time pipe wall thickness of each multiphase flow pipeline segment. Based on the corrosion degree evaluation results of all multiphase flow pipeline segments, the corrosion degree of the multiphase flow pipeline to be evaluated is evaluated.

[0106] Optionally, in the above technical solution, the process of the corrosion degree assessment subunit evaluating the corrosion degree of any multiphase flow pipeline section includes:

[0107] Obtain the wall thickness of a plurality of points in any multiphase flow pipeline section, calculate the average value of the wall thickness of the plurality of points, and use the average value as the real-time wall thickness of any multiphase flow pipeline section;

[0108] Calculate the thickness ratio between the average value and the preset thickness of the pipe wall. The calculation formula of the thickness ratio is: T = t / T0;

[0109] Wherein, T represents the thickness ratio, t represents the average value, and T0 represents the preset thickness of the pipe wall;

[0110] When T is less than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is corroded;

[0111] When T is equal to 1, the corrosion degree evaluation result of any multiphase flow pipeline section is not corroded;

[0112] When T is greater than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is that there is deposit.

[0113] Optionally, in the above technical solution, the corrosion degree assessment subunit is further specifically used for:

[0114] Presetting a first corrosion preset number and a second corrosion preset number, wherein the first corrosion preset number is smaller than the second corrosion preset number, and obtaining the number m of multiphase flow pipeline sections where all T values ​​are smaller than 1;

[0115] When m is less than the first corrosion preset number and greater than 0, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as mild corrosion; when m is greater than the first corrosion preset number and less than the second corrosion preset number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as moderate corrosion;

[0116] When m is greater than the second preset corrosion number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as severe corrosion.

[0117] Optionally, in the above technical solution, the data analysis unit 204 further includes a metal fatigue degree assessment submodule, which is used to:

[0118] When the fluid in the multiphase flow pipeline to be evaluated is a mixture of crude oil and natural gas, the real-time temperature and pressure in the multiphase flow pipeline to be evaluated are obtained, and the density of the mixed fluid is predicted according to the density calculation formula. The density calculation formula is: Where ρ is the density of the mixed fluid, P is the pressure, R is the gas constant, T is the real-time temperature, and B is the Debye constant.

[0119] Optionally, in the above technical solution, the metal fatigue degree assessment submodule is further used to:

[0120] The stress amplitude of the multiphase flow pipeline to be evaluated under the conditions of real-time temperature and density of the mixed fluid is calculated through an empirical model, and the fatigue life of the multiphase flow pipeline to be evaluated is calculated using the relationship between stress amplitude and fatigue life in the SN curve;

[0121] Preset a preset fatigue life, calculate the difference between the preset fatigue life and the fatigue life of the multiphase flow pipeline to be evaluated, and obtain the fatigue life margin;

[0122] Presetting a first fatigue life preset margin and a second fatigue life preset margin, wherein the first fatigue life preset margin is smaller than the second fatigue life preset margin;

[0123] When the fatigue life margin is greater than the second fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue;

[0124] When the fatigue life margin is not greater than the second fatigue life preset margin and greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue;

[0125] When the fatigue life margin is not greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue.

[0126] Optionally, in the above technical solution, the data analysis unit 204 further includes a comprehensive evaluation module, which is used to:

[0127] Scoring the multiphase flow pipeline to be assessed according to its blockage, corrosion and fatigue levels, and evaluating the network status of the multiphase flow pipeline to be assessed based on the scoring results;

[0128] Obtain a blockage score according to the blockage degree of the multiphase flow pipeline to be evaluated. When the blockage degree of the multiphase flow pipeline to be evaluated is light blockage, the blockage score is 1; when the blockage degree of the multiphase flow pipeline to be evaluated is moderate blockage, the blockage score is 2; when the blockage degree of the multiphase flow pipeline to be evaluated is severe blockage, the blockage score is 3;

[0129] A corrosion score is obtained according to the corrosion degree of the multiphase flow pipeline to be evaluated. When the corrosion degree of the multiphase flow pipeline to be evaluated is mild corrosion, the corrosion score is 1; when the corrosion degree of the multiphase flow pipeline to be evaluated is moderate corrosion, the corrosion score is 2; when the corrosion degree of the multiphase flow pipeline to be evaluated is severe corrosion, the corrosion score is 3;

[0130] A fatigue score is obtained according to the metal fatigue degree of the multiphase flow pipeline to be evaluated. When the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue, the fatigue score is 1; when the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue, the fatigue score is 2; when the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue, the fatigue score is 3;

[0131] The scoring result is the sum of the blockage score, corrosion score and fatigue score;

[0132] Presetting a first summed preset value and a second summed preset value;

[0133] When the sum value is less than the first sum preset value, the evaluation result of the pipe network state of the multiphase flow pipeline to be evaluated is a normal state;

[0134] When the sum value is not less than the first sum preset value and less than the second sum preset value, the evaluation result of the pipe network state of the multiphase flow pipeline to be evaluated is a warning state;

[0135] When the sum value is not less than the second sum preset value, the evaluation result of the pipeline network state of the multiphase flow pipeline to be evaluated is a fault state.

[0136] Optionally, in the above technical solution, the data analysis unit 204 is also used to: treat each multiphase flow pipeline in the oil and gas pipeline network as a multiphase flow pipeline to be evaluated, perform a status evaluation on each multiphase flow pipeline, and obtain the pipeline network status of each multiphase flow pipeline in each oil and gas pipeline network.

[0137] It should be noted that the beneficial effects of the oil and gas pipeline network status assessment system 200 provided in the above embodiment are the same as the beneficial effects of the oil and gas pipeline network status assessment method described above, and will not be repeated here. In addition, when implementing its functions, the system provided in the above embodiment is only illustrated by the division of the above functional modules. In actual applications, the above functions can be assigned to different functional modules as needed, that is, the system can be divided into different functional modules according to actual conditions to complete all or part of the functions described above. In addition, the system and method embodiments provided in the above embodiment are based on the same concept. The specific implementation process is detailed in the method embodiment and will not be repeated here.

[0138] like Figure 3 As shown, a computer device 300 according to an embodiment of the present invention includes a processor 320 coupled to a memory 310. The memory 310 stores at least one computer program 330. The at least one computer program 330 is loaded and executed by the processor 320, so that the computer device 300 implements any of the above-mentioned oil and gas pipeline network status assessment methods. Specifically:

[0139] The computer device 300 may vary significantly due to different configurations or performance, and may include one or more processors 320 (Central Processing Units, CPUs) and one or more memories 310. The one or more memories 310 store at least one computer program 330, which is loaded and executed by the one or more processors 320 to enable the computer device 300 to implement any of the oil and gas pipeline network status assessment methods provided in the above embodiments. Of course, the computer device 300 may also include components such as a wired or wireless network interface, a keyboard, and input / output interfaces for input and output. The computer device 300 may also include other components for implementing device functions, which are not detailed here.

[0140] A computer-readable storage medium according to an embodiment of the present invention stores at least one computer program, which is loaded and executed by a processor to enable a computer to implement any of the above-mentioned oil and gas pipeline network status assessment methods.

[0141] Alternatively, the computer-readable storage medium may be a read-only memory (ROM), a random access memory (RAM), a compact disc (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, or the like.

[0142] In an exemplary embodiment, a computer program product or computer program is also provided. The computer program product or computer program includes computer instructions stored in a computer-readable storage medium. A processor of a computer device reads the computer instructions from the computer-readable storage medium and executes the computer instructions, causing the computer device to perform any of the aforementioned oil and gas pipeline network condition assessment methods.

[0143] It should be noted that the terms "first," "second," and the like in the specification and claims of this application are used to distinguish similar objects and to define a specific order or precedence. Where appropriate, the order used for similar objects may be interchanged, such that the embodiments of the present application described herein can be implemented in an order other than the order shown or described.

[0144] Those skilled in the art will appreciate that the present invention may be implemented as a system, method, or computer program product. Therefore, the present invention may be implemented in the following forms: entirely in hardware, entirely in software (including firmware, resident software, microcode, etc.), or in a combination of hardware and software, generally referred to herein as a "circuit," "module," or "system." Furthermore, in some embodiments, the present invention may be implemented in the form of a computer program product embodied in one or more computer-readable media containing computer-readable program code.

[0145] Any combination of one or more computer-readable media can be used. The computer-readable medium can be a computer-readable signal medium or a computer-readable storage medium. The computer-readable storage medium can be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, device or component, or any combination thereof. More specific examples of computer-readable storage media (a non-exhaustive list) include: an electrical connection with one or more wires, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination thereof. In the present invention, a computer-readable storage medium can be any tangible medium containing or storing a program that can be used by or in conjunction with an instruction execution system, device or device.

[0146] Although the embodiments of the present invention have been shown and described above, it will be understood that the above embodiments are illustrative and are not to be construed as limitations on the present invention. A person skilled in the art may change, modify, replace and modify the above embodiments within the scope of the present invention.

Claims

1. A method for evaluating the status of an oil and gas pipeline network, characterized in that: include: Obtaining and evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and the outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network; Obtaining and evaluating the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated; Obtaining and predicting the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimating the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid; Evaluating the network status of the multiphase flow pipeline to be evaluated according to the blockage degree, corrosion degree and metal fatigue degree of the multiphase flow pipeline to be evaluated; Evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and the outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network, including: The flow difference and flow ratio between the inlet flow and the outlet flow are calculated. The flow difference is calculated as follows: , the calculation formula of the flow ratio is: ,in, represents the flow difference, represents the inlet flow rate, represents the outlet flow rate, represents the flow ratio; Calculate the flow quotient of the flow difference and the flow ratio, and the calculation formula of the flow quotient is: , represents the flow quotient value; presetting a preset flow quotient value, comparing the flow quotient value with the preset flow quotient value, and evaluating the blockage degree of the multiphase flow pipeline to be evaluated based on the comparison result; Comparing the flow quotient value with the preset flow quotient value, and evaluating the blockage degree of the multiphase flow pipeline to be evaluated according to the comparison result, includes: When the flow quotient value is less than the preset flow quotient value, it is determined that the multiphase flow pipeline to be evaluated is not blocked, and the blockage degree of the multiphase flow pipeline to be evaluated is 0; When the flow quotient value is not less than the preset flow quotient value, determining that the multiphase flow pipeline to be evaluated is blocked, and calculating a flow quotient difference between the flow quotient value and the preset flow quotient value; Presetting a first preset flow quotient difference value and a second preset flow quotient difference value, wherein the first preset flow quotient difference value is smaller than the second preset flow quotient difference value; When the flow quotient difference is less than a first preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as slight blockage; When the flow quotient difference is not less than the first preset flow quotient difference and less than the second preset flow quotient difference, the blockage degree of the multiphase flow pipeline to be evaluated is assessed as moderate blockage; When the flow quotient difference is not less than the second preset flow quotient difference, it is assessed that the blockage degree of the multiphase flow pipeline to be assessed is severe blockage.

2. The method for evaluating the status of an oil and gas pipeline network according to claim 1, wherein: Evaluating the corrosion degree of the multiphase flow pipeline to be evaluated according to the real-time wall thickness of the multiphase flow pipeline to be evaluated, including: Presetting a preset pipe wall thickness, dividing the multiphase flow pipeline to be evaluated into n segments on average, and obtaining n multiphase flow pipeline segments; The corrosion degree of each multiphase flow pipeline segment is evaluated by respectively using the preset pipe wall thickness and the real-time pipe wall thickness of each multiphase flow pipeline segment. Based on the corrosion degree evaluation results of all the multiphase flow pipeline segments, the corrosion degree of the multiphase flow pipeline to be evaluated is evaluated.

3. The method for evaluating the status of an oil and gas pipeline network according to claim 2, wherein: Evaluate the corrosion severity of any multiphase flow pipeline section, including: Obtaining the pipe wall thicknesses at a plurality of points in the any multiphase flow pipeline section, calculating an average value of the pipe wall thicknesses at the plurality of points, and using the average value as the real-time pipe wall thickness of the any multiphase flow pipeline section; The thickness ratio between the average value and the preset thickness of the pipe wall is calculated, and the calculation formula of the thickness ratio is: ; in, represents the thickness ratio, represents the average value, Indicates the preset thickness of the pipe wall; When T is less than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is corroded; When T is equal to 1, the corrosion degree evaluation result of any multiphase flow pipeline section is not corroded; When T is greater than 1, the corrosion degree evaluation result of any multiphase flow pipeline section is that there is deposit.

4. The method for evaluating the status of an oil and gas pipeline network according to claim 3, wherein: Evaluating the corrosion degree of the multiphase flow pipeline to be evaluated based on the corrosion degree evaluation results of all the multiphase flow pipeline sections, including: Presetting a first corrosion preset number and a second corrosion preset number, wherein the first corrosion preset number is smaller than the second corrosion preset number, and obtaining the number m of multiphase flow pipeline sections where all T values ​​are smaller than 1; When m is less than the first corrosion preset number and greater than 0, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as mild corrosion; When m is greater than the first corrosion preset number and less than the second corrosion preset number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as moderate corrosion; When m is greater than the second preset corrosion number, the corrosion degree of the multiphase flow pipeline to be evaluated is assessed as severe corrosion.

5. The method for evaluating the status of an oil and gas pipeline network according to claim 4, characterized in that: The fluid in the multiphase flow pipeline to be evaluated is a mixed fluid of crude oil and natural gas, and the density of the fluid in the multiphase flow pipeline to be evaluated is the density of the mixed fluid; Estimating the metal fatigue degree of the multiphase flow pipeline to be evaluated according to the density of the fluid, including: The stress amplitude of the multiphase flow pipeline to be evaluated under the conditions of the real-time temperature and the density of the mixed fluid is calculated using an empirical model, and the fatigue life of the multiphase flow pipeline to be evaluated is calculated using the relationship between the stress amplitude and fatigue life in the SN curve; Presetting a preset fatigue life, calculating the difference between the preset fatigue life and the fatigue life of the multiphase flow pipeline to be evaluated, and obtaining a fatigue life margin; Presetting a first fatigue life preset margin and a second fatigue life preset margin, wherein the first fatigue life preset margin is smaller than the second fatigue life preset margin; When the fatigue life margin is greater than the second fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue; When the fatigue life margin is not greater than the second fatigue life preset margin and greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue; When the fatigue life margin is not greater than the first fatigue life preset margin, the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue.

6. The method for evaluating the status of an oil and gas pipeline network according to claim 5, characterized in that: Evaluating the network status of the multiphase flow pipeline to be evaluated according to the blockage degree, corrosion degree, and metal fatigue degree of the multiphase flow pipeline to be evaluated, including: Scoring the multiphase flow pipeline to be evaluated according to the blockage degree, the corrosion degree, and the fatigue degree of the multiphase flow pipeline to be evaluated, and evaluating the pipeline network status of the multiphase flow pipeline to be evaluated according to the scoring result; Obtaining a blockage score according to the blockage degree of the multiphase flow pipeline to be evaluated, wherein when the blockage degree of the multiphase flow pipeline to be evaluated is mild blockage, the blockage score is 1; when the blockage degree of the multiphase flow pipeline to be evaluated is moderate blockage, the blockage score is 2; and when the blockage degree of the multiphase flow pipeline to be evaluated is severe blockage, the blockage score is 3; Obtaining a corrosion score according to the corrosion degree of the multiphase flow pipeline to be evaluated, wherein when the corrosion degree of the multiphase flow pipeline to be evaluated is mild corrosion, the corrosion score is 1; when the corrosion degree of the multiphase flow pipeline to be evaluated is moderate corrosion, the corrosion score is 2; and when the corrosion degree of the multiphase flow pipeline to be evaluated is severe corrosion, the corrosion score is 3; Obtaining a fatigue score according to the metal fatigue degree of the multiphase flow pipeline to be evaluated, wherein when the metal fatigue degree of the multiphase flow pipeline to be evaluated is mild fatigue, the fatigue score is 1; when the metal fatigue degree of the multiphase flow pipeline to be evaluated is moderate fatigue, the fatigue score is 2; and when the metal fatigue degree of the multiphase flow pipeline to be evaluated is severe fatigue, the fatigue score is 3; The scoring result is the sum of the blockage score, corrosion score and fatigue score; Presetting a first summed preset value and a second summed preset value; When the sum value is less than the first sum preset value, the evaluation result of the pipe network state of the multiphase flow pipeline to be evaluated is a normal state; When the sum value is not less than the first sum preset value and less than the second sum preset value, the evaluation result of the pipeline network state of the multiphase flow pipeline to be evaluated is a warning state; When the sum value is not less than the second sum preset value, the evaluation result of the pipeline network state of the multiphase flow pipeline to be evaluated is a fault state.

7. A state assessment system for an oil and gas pipeline network, characterized in that: A method for evaluating the state of an oil and gas pipeline network according to any one of claims 1 to 6 is adopted, comprising a fluid flow detection unit, a pipe wall thickness detection unit, a temperature detection unit and a data analysis unit; The fluid flow detection unit is used to: obtain the inlet flow rate and outlet flow rate of the multiphase flow pipeline to be evaluated in the oil and gas pipeline network; The pipe wall thickness detection unit is used to: obtain the real-time pipe wall thickness of the multiphase flow pipeline to be evaluated; The temperature detection unit is used to: obtain the real-time temperature of the multiphase flow pipeline to be evaluated; The data analysis unit is used to: evaluate the blockage degree of the multiphase flow pipeline to be evaluated based on the inlet flow rate and the outlet flow rate of the multiphase flow pipeline to be evaluated; evaluate the corrosion degree of the multiphase flow pipeline to be evaluated based on the real-time wall thickness of the multiphase flow pipeline to be evaluated; predict the density of the fluid in the multiphase flow pipeline to be evaluated based on the real-time temperature of the environment in which the multiphase flow pipeline to be evaluated is located, and estimate the metal fatigue degree of the multiphase flow pipeline to be evaluated based on the density of the fluid; and evaluate the pipeline network status of the multiphase flow pipeline to be evaluated based on the blockage degree, corrosion degree and metal fatigue degree of the multiphase flow pipeline to be evaluated.

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