WO2020082749A1 - 油气集输立管系统有害流型的预警方法、控制方法及系统 - Google Patents

油气集输立管系统有害流型的预警方法、控制方法及系统 Download PDF

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Publication number
WO2020082749A1
WO2020082749A1 PCT/CN2019/090556 CN2019090556W WO2020082749A1 WO 2020082749 A1 WO2020082749 A1 WO 2020082749A1 CN 2019090556 W CN2019090556 W CN 2019090556W WO 2020082749 A1 WO2020082749 A1 WO 2020082749A1
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riser
gas
liquid
early warning
pressure difference
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French (fr)
Inventor
郭烈锦
邹遂丰
吴全红
刘威志
徐强
郭龙进
周文波
赵向远
姚添
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Xian Jiaotong University
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Xian Jiaotong University
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • G—PHYSICS
    • G05—CONTROLLING; REGULATING
    • G05D—SYSTEMS FOR CONTROLLING OR REGULATING NON-ELECTRIC VARIABLES
    • G05D16/00—Control of fluid pressure
    • G05D16/20—Control of fluid pressure characterised by the use of electric means
    • G05D16/2006—Control of fluid pressure characterised by the use of electric means with direct action of electric energy on controlling means
    • G05D16/2013—Control of fluid pressure characterised by the use of electric means with direct action of electric energy on controlling means using throttling means as controlling means
    • G05D16/2026—Control of fluid pressure characterised by the use of electric means with direct action of electric energy on controlling means using throttling means as controlling means with a plurality of throttling means
    • G05D16/204—Control of fluid pressure characterised by the use of electric means with direct action of electric energy on controlling means using throttling means as controlling means with a plurality of throttling means the plurality of throttling means being arranged in parallel
    • G—PHYSICS
    • G08—SIGNALLING
    • G08B—SIGNALLING SYSTEMS, e.g. PERSONAL CALLING SYSTEMS; ORDER TELEGRAPHS; ALARM SYSTEMS
    • G08B21/00—Alarms responsive to a single specified undesired or abnormal condition and not otherwise provided for
    • G08B21/02—Alarms for ensuring the safety of persons
    • G08B21/12—Alarms for ensuring the safety of persons responsive to undesired emission of substances, e.g. pollution alarms
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/02—Total factory control, e.g. smart factories, flexible manufacturing systems [FMS] or integrated manufacturing systems [IMS]

Definitions

  • the invention belongs to the field of marine oil and gas field flow safety guarantee, and particularly relates to an early warning method, a control method and a system for harmful flow patterns of an oil and gas gathering and transportation riser system.
  • the prior art uses gas and liquid distribution at three different positions on the riser and from the top of the riser to the separator (which can be characterized by the pressure difference in the vertical section, and the friction pressure drop is relative to the weight The potential pressure drop is negligible) to realize the rapid identification of harmful flow patterns.
  • a shut-off valve and / or regulating valve between the top of the riser and the separator.
  • the throttle coefficient changes, causing the pressure difference of this section of the pipeline to change, resulting in signal samples of different flow patterns.
  • the characteristic distribution also changes; and valve adjustment is a common process in oil and gas production, so the identification result of this scheme is very sensitive to the valve opening.
  • the PID control can be performed by the pressure signal at the bottom of the riser, but the increase of the liquid phase itself makes the occurrence of severe liquid plug flow less likely, which only shows that the control model can adapt to different flow rates. It was noted that the procedure was initiated after the occurrence of severe liquid plug flow, and it still took several cycles to eliminate it.
  • PID control can be performed through the pressure signal at the pipeline inlet to suppress pressure fluctuations.
  • This method is only applicable to the flow control between two platforms (the pipeline is generally U-shaped), and is not applicable to the flow control between the wellhead and the platform (in the case of a long pipeline).
  • the purpose of the present invention is to provide an early warning method, a control method and a system for harmful flow patterns of oil and gas gathering and riser systems to overcome the deficiencies of the prior art.
  • the present invention adopts the following technical solutions:
  • the early warning method for harmful flow patterns in the oil and gas gathering riser system includes the following steps:
  • Step 1). Continuously and quickly identify the overall flow pattern in the pipeline and obtain the dimensionless average value of the differential pressure signal through at least three differential pressure signals on the gathering and riser system.
  • the at least three differential pressure signals include at least one subsea pipeline Pressure difference DP1 and at least two riser pressure differences, the two riser pressure differences include total riser pressure difference DP2 and riser partial pressure difference DP3;
  • Step 2 Train the first support vector machine with the formation mechanism and position parameter of the liquid plug in the submarine pipeline; train the second support vector machine with the formation mechanism and liquid plug formation position parameter of the bottom of the riser;
  • Step 3 If the dimensionless average value of the total pressure difference DP2 of the riser is less than 0.4, input at least 3 pressure difference signals to the first support vector machine for judgment, and if at least one is judged to be "unstable flow pattern", issue Early warning and judging that the liquid plug is formed in the submarine pipeline, otherwise no early warning will be given; if the dimensionless average value of the total pressure difference DP2 of the riser is greater than 0.4, at least 3 differential pressure signals will be input into the second support vector machine for judgment. When the vector machine judges that a sample is recognized as "unstable flow pattern”, it recognizes three consecutive samples after the sample. If all three consecutive samples are identified as “unstable flow pattern", then Issue an early warning, and judge that the liquid plug is formed at the bottom of the riser, otherwise no early warning will be issued.
  • the signal parameters input to the first support vector machine or the second support vector machine include the dimensionless mean and standard deviation of the submarine pipeline pressure difference DP1, the dimensionless mean, extreme range and local riser pressure difference of the riser pressure difference DP2 The dimensionless mean and standard deviation of DP3.
  • the dimensionless method of the submarine pipeline pressure difference signal DP1 and the riser pressure difference signal DP2 is to divide the signal value by the pressure difference when the pressure difference test section is filled with a stationary liquid phase.
  • the non-dimensional method of the riser local differential pressure signal DP3 is to divide the signal value by the frictional pressure difference when the liquid phase flows through the differential pressure test section at a unit velocity under the assumption of a hydraulically smooth tube.
  • samples used for SVM training are taken from the process of steady-state flow, that is, the process of inlet flow and outlet pressure is constant.
  • the specific form of SVM is:
  • the support vector machine toolkit based on Matlab is used to complete the training of the support vector machine, and the feature vector of the sample to be tested is input into the support vector machine to obtain the result of the flow pattern recognition.
  • a method for controlling harmful flow patterns in an oil and gas gathering and riser system includes the following steps:
  • a harmful flow pattern control system in a marine oil and gas gathering and transportation riser system includes a monitoring device and a control device.
  • the monitoring device includes a computer control module and a pressure sensor for monitoring the pressure difference of different sections of the gathering and transportation riser.
  • the data collection module is connected to the pressure sensor and is used to collect the pressure difference at different sections of the gathering riser.
  • the processing module is used to write the above warning method and control method program for the data collection module. Collect data for processing and signal output;
  • the control device includes a gas injection device communicating with the bottom of the riser and a throttle valve connected to the upper end of the riser.
  • the end of the throttle valve on the riser is connected with a liquid plug trap.
  • the gas outlet of the liquid plug trap is provided with a first
  • a gas phase valve and a liquid phase outlet of the liquid plug trap are provided with a first liquid phase valve.
  • the first gas phase valve and the first liquid phase valve outlet are connected to a gas-liquid separator, and the gas phase outlet of the gas-liquid separator is connected to a second gas phase
  • the valve and the liquid phase outlet of the gas-liquid separator are connected with a second liquid phase valve; the processing module is connected to each control valve.
  • the gathering and transportation riser includes a submarine pipeline and a riser, the submarine pipeline is provided with a first pressure difference sensor, and the riser is provided with at least two pressure difference sensors.
  • the present invention has the following beneficial technical effects:
  • the early warning method of harmful flow patterns in the oil and gas gathering and transportation riser system of the present invention carries out training and support vector machine training by adopting the formation mechanism and liquid plug formation position parameters of the normal submarine pipeline and the riser bottom; At least 3 differential pressure signals continuously and quickly identify the overall flow pattern in the pipeline and obtain the dimensionless average value of the differential pressure signal, relying on the monitoring of the formation of long liquid plugs in the submarine pipeline and the average value of each differential pressure signal to the rapid change of flow rate Response, realize the early warning of the instability of the gas-liquid interface and the liquid plug caused by the pipeline structure, and correspondingly predict that the position of the liquid plug is the bottom of the submarine pipeline and the riser, to achieve accurate judgment of the position of the liquid plug.
  • the method has high early warning reliability and low false alarm rate, and can significantly improve the margin of mobile security guarantee.
  • a method for controlling harmful flow patterns in an oil and gas gathering and riser system Through accurate judgment and early warning of the position of the liquid plug, it can have enough time for the control device to respond, avoiding the decrease in the recognition accuracy rate caused by the change in valve opening In order to ensure the reliability of early warning, through the effective use of upstream signals, advanced control is achieved, which can avoid the formation of serious liquid plug flow in a large range.
  • a harmful flow pattern control system in a marine oil and gas gathering and transportation riser system by setting a gas injection device connected to the bottom of the riser and a throttle valve connected to the upper end of the riser, and then in the liquid plug trap and gas-liquid separator Valves are installed at the gas-liquid inlet and outlet. Valves are installed at the gas-liquid inlet and outlet installed in the liquid plug trap and gas-liquid separator. Since the advance of the warning is relatively small, it is necessary to close the throttling valve at the top of the small riser properly The gas outlet valve of the separator and the liquid plug trap, and the liquid outlet valve of the atmospheric liquid separator and the liquid plug trap are opened appropriately. Because the space of the liquid plug trap is released in advance, the gas and liquid at the top of the riser Both the volume of the separator and the liquid plug trap can be reduced to release platform space and reduce platform load.
  • FIG. 1 is a schematic diagram of the connection structure of the device of the present invention.
  • Figure 2 is a schematic diagram of the early warning and control response method.
  • Fig. 3 is a signal waveform diagram of the transition process to a harmful flow pattern; Fig. 3 (a) shows that the liquid plug is formed on the submarine pipeline; Fig. 3 (b) shows that the liquid plug is formed on the bottom of the riser.
  • Fig. 4 is the effect diagram after the control device responds when the inlet flow rate changes after the gas injection and the throttling control respond sequentially, and the liquid plug is predicted to form at the bottom of the riser.
  • FIG. 5 is a diagram of the transition effect of the flow pattern without applying any control method.
  • a harmful flow pattern control system in a marine oil and gas gathering and riser system includes a monitoring device and a control device.
  • the monitoring device includes a computer control module and a pressure difference for monitoring different sections of the gathering and riser.
  • the pressure sensor, the computer control module is equipped with a processing module and a data collection module.
  • the data collection module is connected to the pressure sensor and used to collect the pressure difference at different sections of the gathering riser.
  • the processing module is used to write the above warning method and control Method program, used to process the data collected by the data collection module and output the signal;
  • the control device includes a gas injection device communicating with the bottom of the riser and a throttle valve connected to the upper end of the riser.
  • the end of the throttle valve on the riser is connected with a liquid plug trap.
  • the gas outlet of the liquid plug trap is provided with a first
  • a gas phase valve and a liquid phase outlet of the liquid plug trap are provided with a first liquid phase valve.
  • the first gas phase valve and the first liquid phase valve outlet are connected to a gas-liquid separator, and the gas phase outlet of the gas-liquid separator is connected to a second gas phase
  • the valve and the liquid phase outlet of the gas-liquid separator are connected with a second liquid phase valve; the processing module is connected to each control valve.
  • the gathering and transportation riser includes a submarine pipeline and a riser.
  • the submarine pipeline is provided with a first differential pressure sensor, and the riser is provided with at least two differential pressure sensors.
  • the invention provides a method for predicting and warning the harmful flow pattern in the marine oil and gas gathering and riser system; the rapid and continuous identification of the overall flow pattern in the pipeline is carried out through the three pressure difference signals on the gathering and riser system.
  • the three signals are the submarine pipeline pressure difference DP1, the riser pressure difference DP2 and the riser partial pressure difference DP3; in this embodiment, the sample length is 10s, and the recognition method used is a support vector machine, but a neural network recognition method can also be used , The samples used for their training are taken from the steady-state process;
  • the reasons for the formation of the liquid plug include the instability of the pipeline structure and the gas-liquid interface (that is, the hydrodynamic force), the corresponding length of the liquid plug and the position where the liquid plug is formed are all closely related to the average value of the DP2 signal of the riser pressure difference. Therefore, first train two support vector machines according to different ranges of the dimensionless mean of the riser pressure difference DP2, and then rely on the two support vector machines for flow pattern recognition; the input parameter of the support vector machine is the dimensionless dimension of the submarine pipeline pressure difference DP1 Mean, standard deviation, dimensionless mean and extreme difference of riser pressure difference DP2, dimensionless mean and standard deviation of riser partial pressure difference DP3;
  • the dimensionless method of the submarine pipeline pressure difference signal DP1 and the riser pressure difference signal DP2 is: dividing the signal value by the pressure difference when the pressure difference test section is filled with a stationary liquid phase;
  • the dimensionless method of the riser local differential pressure signal DP3 is: dividing the signal value by the frictional pressure difference when the liquid phase flows through the differential pressure test section at a unit velocity under the assumption of a hydraulically smooth tube.
  • the samples used for SVM training are taken from the steady-state flow process, that is, the process of constant inlet flow and outlet pressure.
  • the specific form of SVM is:
  • x is the feature vector of the sample to be tested;
  • x i and y i are the feature vectors of the known samples and the type of flow type (represented by 1 or -1);
  • ⁇ i and b are the parameters of the support vector machine.
  • Confirm ;
  • K is a kernel function, which is selected as the radial basis function in this embodiment;
  • f (x) is 1 or -1 is the recognition result.
  • Matlab-based support vector machine toolkit download link: https://www.esat.kuleuven.be/sista/lssvmlab/) to complete the training of the support vector machine, and input the feature vector of the sample to be tested into the support vector machine to get the stream Type recognition results.
  • the first support vector machine is trained using the formation mechanism and position parameters of the liquid plug formation in the submarine pipeline; the second support vector machine is trained using the formation mechanism and position parameter of the liquid plug formation at the bottom of the riser, due to the 2 support vectors
  • the machine corresponds to different liquid plug formation mechanism and liquid plug formation position, so the parameters obtained by their training are different.
  • the present invention tests the two trained support vector machines by collecting some samples of the steady-state flow process under the condition that the opening of the regulating valve at the top of the riser is different. The recognition accuracy of these samples is greater than 90%, indicating that it is used for The early warning flow pattern recognition model is reliable enough.
  • the two trained support vector machines input the collected signal parameters into the two trained support vector machines, and get the corresponding results: specifically, if the dimensionless mean of the neutral pressure difference DP2 of the signal samples is less than 0.4, the first support vector machine is used for recognition. If the dimensionless mean of the riser pressure difference is greater than 0.4, the second support vector machine is used for identification.
  • the first support vector machine determines that a sample is identified as "unstable flow pattern”, it issues an early warning and judges The liquid plug is formed in the submarine pipeline; when the second support vector machine judges that a sample is identified as “unstable flow pattern”, it will identify three consecutive samples after the sample, if all three consecutive samples are identified When it is recognized as “unstable flow pattern”, an early warning is issued, and it is judged that the liquid plug is formed at the bottom of the riser, otherwise no early warning is issued.
  • the support vector machine output "1" means “stable flow pattern”
  • the output "-1" means "unstable flow pattern”.
  • the gas flow rate in the situation shown in FIG. 3 (a) is low, and the serious liquid plug flow is caused by the pipeline structure, and the liquid plug is formed at the bottom of the riser; in this embodiment, this kind of The early warning amount of severe liquid slug flow in the form is 100 ⁇ 1360s, and all 18 transitions trigger the early warning; the situation shown in Figure 3 (b) is that the gas flow rate is high, the gas-liquid interface is unstable, and a long Hydrodynamic liquid plug; this type of liquid plug early warning advance is 20 ⁇ 960s, and 15 times of 16 changes trigger early warning.
  • the trigger rate of early warning in this embodiment is 97%, indicating that the present invention has high reliability.
  • the liquid plug is predicted to form in the submarine pipeline, because the advance of the warning is relatively small (but it is still sufficient for the control valve, but it is not necessarily eliminated), it is necessary to close the throttle valve at the top of the small riser and close the small gas and liquid.
  • the gas outlet valve of the separator and the liquid plug trap, and the liquid outlet valve of the atmospheric liquid separator and the liquid plug trap are opened appropriately.
  • the purpose of the operation of the above valves is to delay the discharge of the liquid plug, maintain the pressure stability of the separator and the liquid plug trap, and release the space of the liquid plug trap to receive the liquid plug.
  • the adjustment amount of the valve is determined by the length of the liquid plug, which can be calculated by the Brill formula (SPE Journal, Vol. 271, pp. 363–378). Since the space of the liquid plug trap is released in advance, after applying the present invention, the volume of the liquid plug trap and / or the gas-liquid separator can be reduced relative to the existing separator control method.
  • the reason for gas injection first is that gas injection can avoid the formation of severe liquid slug flow during the transient process of flow rate change, but throttle cannot be guaranteed to be avoided; if the warning is triggered at a later time, after closing the small throttle, the riser pressure difference There will still be a large fluctuation of one or several cycles (although the amplitude is smaller than that without throttling), and then the amplitude of the fluctuation will gradually decrease. Closing the small throttle first and then closing the gas injection valve will ensure that no serious slug flow will reappear during the control process.

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Abstract

一种油气集输立管系统有害流型的预警方法、控制方法及系统，通过采用正常海底管道与立管底部液塞形成机理与液塞形成位置参数进行训练支持向量机训练；然后对集输立管系统上至少3处压差信号对管道内的整体流型进行连续快速识别并获取压差信号的无量纲均值，依靠对海底管道内长液塞的形成的监测以及各压差信号均值对流量变化的快速响应，实现对气液界面不稳定性以及管道结构所致液塞的预警，并相应预报出液塞形成的位置分别是海底管道以及立管底部，实现液塞位置的精准判断，预警发出后，有足够的时间供控制装置响应，以避免有害流型的形成或避免其造成危害，该方法预警可靠性高、误报率低，可显著提高流动安全保障的裕度。

Description

油气集输立管系统有害流型的预警方法、控制方法及系统 技术领域
本发明属于海洋油气田流动安全保障领域，具体涉及油气集输立管系统有害流型的预警方法、控制方法及系统。
背景技术
在海洋油气开发中，通过管道将海底采出的油气等产物举升至海面生产平台。由于一座平台通常汇集多口油井的产出物，各油井至平台间的距离较长，管道自井口引出后先沿海床铺设，到达平台下方后脱离海床到达海面；其中自脱离海床处至海面平台的管段称为立管。当气液流量较低时，立管内易形成长液塞，与气相交替流出，造成出口流量的剧烈波动，即不稳定流型，这种流型称为严重液塞流。此外，若管道较粗，在一定气液流量范围内由于气液相界面的不稳定性，在海底管道内易形成较长的水动力液塞，也造成管道出口流量的大幅波动。以严重液塞流为代表的不稳定流型给海洋油气生产带来诸多危害，如产量剧烈波动、压力剧烈波动与管道振动、气液分离器断流或溢流、加剧管道腐蚀与结蜡等，不仅影响生产效率，而且严重危害管道、平台及下游设备的安全。工程上需对这些有害流型进行及时识别、超前预警，以避免其生成或其造成危害。
为达流型快速识别的目的，现有技术通过立管上以及立管顶部至分离器之间的3个不同位置处气液相分布(可由垂直段压差表征，摩阻压降相对于重位压降可忽略不计)的耦合关系实现有害流型的快速识别。通常，立管顶部至分离器间装有截止阀和/或调节阀，当阀门开度发生变化的时候，节流系 数发生变化，引起这一段管道压差的变化，使得不同流型的信号样本特征分布也发生变化；而阀门的调节是油气生产中的常见过程，因此该方案的识别结果对阀门开度非常敏感。
或者通过气液分离器和液塞捕集器出口的气液流量与分离器内的压力、液位信号进行总体积流量与液体流量控制，以保证分离器与液塞捕集器的安全。显然，这种方法并不涉及管道内流型的调控，并不能防止严重液塞流的形成。
或者通过对分离器自身压力、液位以及立管压差信号组成串级PID控制回路。由于分离器压力的调节需较长时间，因此该方法虽然对分离器的安全保障起到了一定的作用，但并不能避免严重液塞流的形成，也不能在其形成后快速消除。
或者通过立管底部压力信号进行PID控制，但液相增大本身使得严重液塞流更不易发生，只能说明控制模型可以适应不同的流量。而注意到在严重液塞流发生之后启动该程序，尚需数个周期才能将其消除。
或者通过管道入口压力信号进行PID控制，以抑制压力的波动。该方法仅适用于2个平台之间的流动控制(管道总体呈现U形)，不适用于井口至平台之间的流动控制(在管道较长的情况下)。
但是采用以上现有技术的作用仅仅是作为防止管道超压，并非是监测严重液塞流的形成，主要是避免在海底安装传感器。论文(Zou et al.,Experimental Thermal and Fluid Science,Vol.96,pp.329–346)研究表明，发生严重液塞流时压力波动自下游向上游传播，因此上游信号并未得到有效利用，不能很好地监测到严重液塞流的形成。
通过以上总结可以发现，以上基于信号波动幅度的控制方法虽然可以在 严重液塞流形成之后对其进行消除，但并不能防止其发生。
发明内容
本发明的目的在于提供油气集输立管系统有害流型的预警方法、控制方法及系统，以克服现有技术的不足。
为达到上述目的，本发明采用如下技术方案：
油气集输立管系统内有害流型的预警方法，包括以下步骤：
步骤1)、通过集输立管系统上至少3处压差信号对管道内的整体流型进行连续快速识别并获取压差信号的无量纲均值，至少3处压差信号包括至少一处海底管道压差DP1和至少两处立管压差，两处立管压差包括立管总压差DP2和立管局部压差DP3；
步骤2)、采用海底管道液塞形成机理与液塞形成位置参数对第一支持向量机进行训练；采用立管底部液塞形成机理与液塞形成位置参数对第二支持向量机进行训练；
步骤3)、如果立管总压差DP2的无量纲均值小于0.4，则将至少3处压差信号输入第一支持向量机进行判断，如果判断至少有一个为“不稳定流型”，则发出预警并判断液塞在海底管道形成，否则不进行预警；如果立管总压差DP2的无量纲均值大于0.4，则将至少3处压差信号输入第二支持向量机进行判断，当第二支持向量机判断某1个样本被识别为“不稳定流型”时，则对该样本起后的连续3个样本进行识别，若连续3个样本均被识别为“不稳定流型”时，则发出预警，并判断液塞在立管底部形成，否则不发出预警。
进一步的，输入第一支持向量机或第二支持向量机的信号参数包括海底管道压差DP1的无量纲均值、标准差，立管压差DP2的无量纲均值、极差及立管局部压差DP3的无量纲均值、标准差。
进一步的，海底管道压差信号DP1和立管压差信号DP2的无量纲化方法是将信号值除以该压差测试段充满静止液相时的压差。
进一步的，立管局部压差信号DP3的无量纲化方法是将信号值除以在水力学光滑管的假设下液相以单位速度流过该压差测试段时的摩阻压差。
进一步的，支持向量机训练所用的样本取自稳态流动的过程，即入口流量与出口压力恒定的过程，支持向量机的具体形式为
Figure PCTCN2019090556-appb-000001
其中，x为待测样本的特征向量；x i、y i分别为已知样本的特征向量以及流型种类(以1或-1表示)；α i与b为支持向量机的参数，通过训练确定；K为核函数，f(x)为1或-1即为识别结果。
进一步的，使用基于Matlab的支持向量机工具包完成支持向量机的训练，将待测样本特征向量输入支持向量机即得到流型识别的结果。
一种油气集输立管系统内有害流型控制方法，包括以下步骤：
若判断液塞在海底管道内形成，则关小立管顶部节流阀门、关小气液分离器与液塞捕集器的气相出口阀门，开大气液分离器与液塞捕集器的液相出口阀门；若判断液塞在立管底部形成，则开启立管底部注气阀门，然后关小立管顶部节流阀门，直到管道内的流动达到新稳态后关闭注气阀门。
一种海洋油气集输立管系统内有害流型控制系统，包括监测装置和控制装置，监测装置包括计算机控制模块和用于监测集输立管不同段位压力差的压力传感器，计算机控制模块内设有处理模块和数据采集模块，数据采集模块连接于压力传感器，用于采集集输立管不同段位上的压力差，处理模块用于写入上述预警方法和控制方法程序，用于对数据采集模块采集数据进行处 理并进行信号输出；
控制装置包括与立管底部连通的注气装置和与立管上端连接的节流阀，立管上节流阀末端连接有液塞捕集器，液塞捕集器的气相出口设有第一气相阀门，液塞捕集器的液相出口设有第一液相阀门，第一气相阀门和第一液相阀门出口连接于气液分离器，气液分离器的气相出口连接有第二气相阀门，气液分离器的液相出口连接有第二液相阀门；处理模块连接于各控制阀门。
进一步的，其中集输立管包括海底管道和立管，海底管道上设有第一压差传感器，立管上设有至少两个压差传感器。
与现有技术相比，本发明具有以下有益的技术效果：
本发明油气集输立管系统内有害流型的预警方法，通过采用正常海底管道与立管底部液塞形成机理与液塞形成位置参数进行训练支持向量机训练；然后对集输立管系统上至少3处压差信号对管道内的整体流型进行连续快速识别并获取压差信号的无量纲均值，依靠对海底管道内长液塞的形成的监测以及各压差信号均值对流量变化的快速响应，实现对气液界面不稳定性以及管道结构所致液塞的预警，并相应预报出液塞形成的位置分别是海底管道以及立管底部，实现液塞位置的精准判断，预警发出后，有足够的时间供控制装置响应，以避免有害流型的形成或避免其造成危害。本方法预警可靠性高、误报率低，可显著提高流动安全保障的裕度。
一种油气集输立管系统内有害流型控制方法，通过对液塞位置的精准判断并进行预警，能够有足够的时间供控制装置响应，避免了阀门开度的变化引起的识别正确率下降，从而保证了预警的可靠性，通过对上游信号的有效利用，实现了超前控制，可在很大范围内避免严重液塞流的形成。
一种海洋油气集输立管系统内有害流型控制系统，通过设置与立管底部 连通的注气装置和与立管上端连接的节流阀，然后在液塞捕集器和气液分离器的气液进出口设置阀门，利用设置于液塞捕集器和气液分离器的气液进出口设置阀门，由于预警的超前量相对较小，则既需要适度关小立管顶部节流阀门、关小气液分离器与液塞捕集器的气相出口阀门，同时适度开大气液分离器与液塞捕集器的液相出口阀门，由于事先释放了液塞捕集器的空间，使立管顶部气液分离器与液塞捕集器的容积均可缩小，以释放平台空间、减轻平台载荷。
附图说明
图1为本发明装置连接结构示意图。
图2为预警及控制响应方法流程简图。
图3为向有害流型转变过程的信号波形图；其中图3(a)为液塞在海底管道形成；图3(b)为液塞在立管底部形成。
图4为注气与节流控制依次响应后入口流量变化后预报液塞在立管底部形成时控制装置响应后的效果图。
图5为不施加任何控制方法的情况下流型的转变效果图。
具体实施方式
下面结合附图对本发明做进一步详细描述：
如图1、图2所示，一种海洋油气集输立管系统内有害流型控制系统，包括监测装置和控制装置，监测装置包括计算机控制模块和用于监测集输立管不同段位压力差的压力传感器，计算机控制模块内设有处理模块和数据采集模块，数据采集模块连接于压力传感器，用于采集集输立管不同段位上的压力差，处理模块用于写入上述预警方法和控制方法程序，用于对数据采集模块采集数据进行处理并进行信号输出；
控制装置包括与立管底部连通的注气装置和与立管上端连接的节流阀，立管上节流阀末端连接有液塞捕集器，液塞捕集器的气相出口设有第一气相阀门，液塞捕集器的液相出口设有第一液相阀门，第一气相阀门和第一液相阀门出口连接于气液分离器，气液分离器的气相出口连接有第二气相阀门，气液分离器的液相出口连接有第二液相阀门；处理模块连接于各控制阀门。
其中集输立管包括海底管道和立管，海底管道上设有第一压差传感器，立管上设有至少两个压差传感器。
本发明给出了一种海洋油气集输立管系统内有害流型的预测预警方法；通过集输立管系统上的3处压差信号对管道内的整体流型进行连续快速识别。3个信号分别为海底管道压差DP1、立管压差DP2与立管局部压差DP3；本实施例中，样本长度为10s，所用识别方法为支持向量机，但也可以用神经网络识别方法，它们训练所用的样本取自稳态过程；
液塞形成的原因包括管道结构与气液相界面不稳定性(即水动力)，相应的液塞长度以及液塞形成的位置不同，均与立管压差DP2信号的均值密切相关。因此，首先按立管压差DP2的无量纲均值的不同范围训练两个支持向量机，然后依靠两个支持向量机进行流型识别；支持向量机的输入参数为海底管道压差DP1的无量纲均值、标准差，立管压差DP2的无量纲均值、极差，立管局部压差DP3的无量纲均值、标准差；
本实施例中，海底管道压差信号DP1和立管压差信号DP2的无量纲化方法是：将信号值除以该压差测试段充满静止液相时的压差；
立管局部压差信号DP3的无量纲化方法是：将信号值除以在水力学光滑管的假设下液相以单位速度流过该压差测试段时的摩阻压差。
支持向量机训练所用的样本取自稳态流动的过程，即入口流量与出口压 力恒定的过程，支持向量机的具体形式为
Figure PCTCN2019090556-appb-000002
其中，x为待测样本的特征向量；x i、y i分别为已知样本的特征向量以及流型种类(以1或-1表示)；α i与b为支持向量机的参数，通过训练确定；K为核函数，本实施例中选为径向基函数；f(x)为1或-1即为识别结果。
使用基于Matlab的支持向量机工具包(下载链接：https://www.esat.kuleuven.be/sista/lssvmlab/)完成支持向量机的训练，将待测样本特征向量输入支持向量机即得到流型识别的结果。
采用海底管道液塞形成机理与液塞形成位置参数对第一支持向量机进行训练；采用立管底部液塞形成机理与液塞形成位置参数对第二支持向量机进行训练，由于2个支持向量机分别对应不同的液塞形成机理与液塞形成位置，因此它们训练得到的参数是不同的。本发明通过在立管顶部调节阀开度不同的情况下另采集了一些稳态流动过程的样本对训练好的2个支持向量机进行测试，这些样本的识别正确率大于90％，表明用于预警的流型识别模型足够可靠。
然后对采集信号参数输入至训练好的2个支持向量机内，得到相应的结果：具体的，若信号样本中立管压差DP2的无量纲均值小于0.4，则使用第一支持向量机进行识别，若立管压差的无量纲均值大于0.4，则使用第二支持向量机进行识别，当第一支持向量机判断某1个样本被识别为“不稳定流型”时，则发出预警，并判断液塞在海底管道形成；当第二支持向量机判断某1个样本被识别为“不稳定流型”时，则对该样本起后的连续3个样本进行识别，若连续3个样本均被识别为“不稳定流型”时，则发出预警，并判 断液塞在立管底部形成，否则不发出预警。本实施例中，支持向量机输出“1”表示“稳定流型”，输出“–1”表示“不稳定流型”。
在某集输立管系统中应用此方法对有害流型进行预警。结合图2对预警的原理进行进一步阐释。图3(a)所示，第220s管道入口流量发生变化后，3个压差信号的均值迅速发生变化；第350s起识别结果出现连续3个“-1”，第370s发出预警时立管压差DP2的波动幅度并未显著升高；直到第550s时DP2的幅度才达到不稳定流型的定义标准，即预警超前量为180s。图3(b)所示，第200s管道入口流量发生变化；第320s时海底管道内形成长液塞，在第330s时识别结果出现“-1”并发出预警；到第380s时液塞进入立管，即预警超前量为50s；第610s又监测到下一个液塞生成(识别结果出现“-1”)，并发出预警。预警一发出，即启动控制响应。
结合集输立管系统内的液塞成因可知，图3(a)所示的情况气相流量较低，严重液塞流由管道结构引起，液塞在立管底部形成；该实施例中这种形式的严重液塞流的预警超前量为100～1360s，18次转变全部触发预警；图3(b)所示的情况气相流量较高，气液相界面不稳定，海底管道内形成较长的水动力液塞；这种形式的液塞预警超前量为20～960s，16次转变有15次触发预警。该实施例中的预警触发率为97％，表明本发明具有很高的可靠性。同时，还对流量变化前后均为稳定流型的情况进行了检验，共14组工况，其中1组在转变过程中出现了水动力长液塞，采用本发明提前60s发出了预警；其余13组未出现长液塞的工况中，虽然有4组工况的暂态过程中识别结果出现了“-1”，但仅有1组出现误报；因此该实施例中的误报率为7％，在很大程度上避免了控制装置的误动作。
若预报液塞在海底管道内形成，由于预警的超前量相对较小(但对于控 制阀门来说仍足够充裕，只是不一定能消除)，则既需要适度关小立管顶部节流阀门、关小气液分离器与液塞捕集器的气相出口阀门，同时适度开大气液分离器与液塞捕集器的液相出口阀门。以上各阀门操作的目的分别是延缓液塞喷发、维持分离器与液塞捕集器的压力稳定、释放液塞捕集器的空间以接收液塞。阀门的调节量由液塞长度决定，水动力液塞长度可通过Brill公式(SPE Journal,Vol.271,pp.363–378)计算。由于事先释放了液塞捕集器的空间，因此应用本发明后，相对于现有分离器控制方法可以缩小液塞捕集器和/或气液分离器的容积。
若预报液塞在立管底部形成，由于预警的超前量相对较大，开启立管底部注气阀门，然后关小立管顶部节流阀门，直到管道内的流动达到新稳态后关闭注气阀门。如果立管底部无注气条件，则直接关小节流阀门。先进行注气的原因是，注气可避免流量变化暂态过程中严重液塞流的形成，但节流无法保证避免；若预警触发的时刻较晚，关小节流阀后，立管压差仍会出现一个或数个周期的大幅波动(虽然幅度比无节流情况下要小一些)，然后波动幅度才逐渐减小。先关小节流阀再关闭注气阀门则保证了控制过程中不再重新出现严重液塞流。
结合图4的控制响应效果对本发明的控制响应方法进行进一步的阐释。图4所示，第94s管道入口流量发生变化后，在第150s发出预警，预警信号一发出即开始实施注气控制；图5所示为相同工况(入口气液流量变化前后的值)、未施加任何控制方法的情况下流型的转变。两者对比可得，预警发出后立刻注气，严重液塞流未形成。随后在第314s时关小节流阀，进入“注气+节流”联合控制阶段，该阶段立管压差DP2的呈现出小幅高频波动；然后在第847s时撤去注气，立管压差DP2的波动频率虽有降低，但幅值无明显 变化，严重液塞流未出现。
通过以上控制使流动状态达到稳态后，即可切换为背景技术中提到的自动控制方法，进行稳态控制。

Claims (9)

  1. 油气集输立管系统内有害流型的预警方法，其特征在于，包括以下步骤：
    步骤1)、通过集输立管系统上至少3处压差信号对管道内的整体流型进行连续快速识别并获取压差信号的无量纲均值，至少3处压差信号包括至少一处海底管道压差DP1和至少两处立管压差，两处立管压差包括立管总压差DP2和立管局部压差DP3；
    步骤2)、采用海底管道液塞形成机理与液塞形成位置参数对第一支持向量机进行训练；采用立管底部液塞形成机理与液塞形成位置参数对第二支持向量机进行训练；
    步骤3)、如果立管总压差DP2的无量纲均值小于0.4，则将至少3处压差信号输入第一支持向量机进行判断，如果判断至少有一个为“不稳定流型”，则发出预警并判断液塞在海底管道形成，否则不进行预警；如果立管总压差DP2的无量纲均值大于0.4，则将至少3处压差信号输入第二支持向量机进行判断，当第二支持向量机判断某1个样本被识别为“不稳定流型”时，则对该样本起后的连续3个样本进行识别，若连续3个样本均被识别为“不稳定流型”时，则发出预警，并判断液塞在立管底部形成，否则不发出预警。
  2. 根据权利要求1所述的油气集输立管系统内有害流型的预警方法，其特征在于，输入第一支持向量机或第二支持向量机的信号参数包括海底管道压差DP1的无量纲均值、标准差，立管压差DP2的无量纲均值、极差及立管局部压差DP3的无量纲均值、标准差。
  3. 根据权利要求1所述的油气集输立管系统内有害流型的预警方法，其特征在于，海底管道压差信号DP1和立管压差信号DP2的无量纲化方法是将信号值除以该压差测试段充满静止液相时的压差。
  4. 根据权利要求1所述的油气集输立管系统内有害流型的预警方法，其特征在于，立管局部压差信号DP3的无量纲化方法是将信号值除以在水力学光滑管的假设下液相以单位速度流过该压差测试段时的摩阻压差。
  5. 根据权利要求1所述的油气集输立管系统内有害流型的预警方法，其特征在于，支持向量机训练所用的样本取自稳态流动的过程，即入口流量与出口压力恒定的过程，支持向量机的具体形式为
    Figure PCTCN2019090556-appb-100001
    其中，x为待测样本的特征向量；x i、y i分别为已知样本的特征向量以及流型种类(以1或-1表示)；α i与b为支持向量机的参数，通过训练确定；K为核函数，f(x)为1或-1即为识别结果。
  6. 根据权利要求1所述的油气集输立管系统内有害流型的预警方法，其特征在于，使用基于Matlab的支持向量机工具包完成支持向量机的训练，将待测样本特征向量输入支持向量机即得到流型识别的结果。
  7. 一种基于权利要求1所述油气集输立管系统内有害流型预警方法的油气集输立管系统内有害流型控制方法，其特征在于，包括以下步骤：
    若判断液塞在海底管道内形成，则关小立管顶部节流阀门、关小气液分离器与液塞捕集器的气相出口阀门，开大气液分离器与液塞捕集器的液相出口阀门；若判断液塞在立管底部形成，则开启立管底部注气阀门，然后关小立管顶部节流阀门，直到管道内的流动达到新稳态后关闭注气阀门。
  8. 一种基于权利要求7控制方法的海洋油气集输立管系统内有害流型控制系统，其特征在于，包括监测装置和控制装置，监测装置包括计算机控制模块和用于监测集输立管不同段位压力差的压力传感器，计算机控制模块内 设有处理模块和数据采集模块，数据采集模块连接于压力传感器，用于采集集输立管不同段位上的压力差，处理模块用于写入上述预警方法和控制方法程序，用于对数据采集模块采集数据进行处理并进行信号输出；
    控制装置包括与立管底部连通的注气装置(4)和与立管上端连接的节流阀(5)，立管上节流阀(5)末端连接有液塞捕集器，液塞捕集器的气相出口设有第一气相阀门(6)，液塞捕集器的液相出口设有第一液相阀门(7)，第一气相阀门(6)和第一液相阀门(7)出口连接于气液分离器，气液分离器的气相出口连接有第二气相阀门(8)，气液分离器的液相出口连接有第二液相阀门(9)；处理模块连接于各控制阀门。
  9. 根据权利要求8所述的一种海洋油气集输立管系统内有害流型控制系统，其特征在于，其中集输立管包括海底管道和立管，海底管道上设有第一压差传感器(1)，立管上设有至少两个压差传感器。
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