WO2017166367A1 - 一种湿天然气气液两相流量计量装置 - Google Patents

一种湿天然气气液两相流量计量装置 Download PDF

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WO2017166367A1
WO2017166367A1 PCT/CN2016/080894 CN2016080894W WO2017166367A1 WO 2017166367 A1 WO2017166367 A1 WO 2017166367A1 CN 2016080894 W CN2016080894 W CN 2016080894W WO 2017166367 A1 WO2017166367 A1 WO 2017166367A1
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gas
phase
natural gas
liquid
flow
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French (fr)
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张丛
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深圳市樊溪电子有限公司
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M10/00—Hydrodynamic testing; Arrangements in or on ship-testing tanks or water tunnels

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  • the invention relates to the technical field of fluid flow measurement, in particular to a wet natural gas gas-liquid two-phase flow metering method and a metering device.
  • the gas production and production volume of gas wells is one of the important data for gas field production and management. It is not only an important basis for formulating production processes, determining production processes and production management methods, but also optimizing gas field production and ensuring rational gas reservoirs. Basic data.
  • the embodiment of the present invention provides a wet natural gas gas-liquid two-phase flow measurement.
  • Method and metering device the technical scheme is as follows:
  • an embodiment of the present invention provides a wet natural gas gas-liquid two-phase flow metering method, and a wet natural gas gas-liquid two-phase flow metering method, wherein the method comprises:
  • the differential pressure ⁇ P i before and after the wet natural gas flows through the orifice plate is collected multiple times in a predefined cycle.
  • liquid phase mass flow rate G d and the gas phase mass flow rate G c are calculated based on the following formula:
  • the method further comprises: collecting the pipeline pressure before the wet natural gas flows through the orifice plate; sampling and testing the wet natural gas, The gas phase operating density ⁇ c and the liquid phase operating density ⁇ d are determined in conjunction with the line pressure.
  • said method further comprising: deriving the volume flow of the wet gas through the gas equation of state of gas, the gas volume flow and in accordance with the The liquid phase volumetric flow rate is calculated by the liquid phase operating density.
  • the frequency of the differential pressure ⁇ P i before and after the collection of the wet natural gas flowing through the orifice plate is at least 20 times per second.
  • the method further comprises: collecting the temperature value of the wet natural gas.
  • an embodiment of the present invention further provides a wet natural gas gas-liquid two-phase flow metering device, the device comprising:
  • Differential acquisition means for collecting a plurality of times before and after differential pressure ⁇ wet gas flowing through orifice plate P i within a predefined period;
  • a flow calculation unit for calculating a liquid phase mass flow rate G d and a gas phase mass flow rate G c based on the following formula:
  • the apparatus further includes: a pressure collecting unit, configured to collect a pipeline pressure before the wet natural gas flows through the orifice plate before the differential pressure ⁇ P i before and after the collecting of the wet natural gas flows through the orifice plate; And a calculating unit for sampling and testing the wet natural gas, and determining the gas phase working density ⁇ c and the liquid phase working density ⁇ d according to the line pressure.
  • a pressure collecting unit configured to collect a pipeline pressure before the wet natural gas flows through the orifice plate before the differential pressure ⁇ P i before and after the collecting of the wet natural gas flows through the orifice plate
  • a calculating unit for sampling and testing the wet natural gas, and determining the gas phase working density ⁇ c and the liquid phase working density ⁇ d according to the line pressure.
  • the flow calculation unit is further configured to: after the calculating the liquid phase mass flow rate G d and the gas phase mass flow rate G c , deriving a gas phase volume flow rate of the wet natural gas by a gas state equation, according to the gas phase volume The liquid phase volume flow is calculated from the flow rate and the liquid phase operating density.
  • the differential pressure collecting unit collects a differential pressure ⁇ P i of the wet natural gas flowing through the orifice plate at least 20 times per second.
  • the apparatus further includes: a temperature collecting unit configured to collect a temperature value of the wet natural gas before the differential pressure ⁇ P i before and after the collected wet natural gas flows through the orifice plate.
  • FIG. 1 is an application scenario diagram provided by an embodiment of the present invention
  • FIG. 3 is a liquid phase flow model diagram of a two-phase flow of an annular flow type according to Embodiment 1 of the present invention.
  • FIG. 4 is a schematic diagram of a vapor-water two-phase flow experimental system according to Embodiment 1 of the present invention.
  • Figure 5 is a graph showing the relationship between the liquid phase flow rate and the statistical variance of the differential pressure square of the orifice plate provided in Example 1 of the present invention
  • Figure 6 is a view showing the first embodiment of the present invention A graph of the relative statistical variance R of the differential pressure square root;
  • Figure 7 is a view of the first embodiment of the present invention with Relationship diagram
  • FIG. 8 is an autocorrelation function diagram and a linear spectrum diagram of differential pressure noise under three operating conditions according to Embodiment 1 of the present invention.
  • Figure 9 is a basic flow diagram of a horizontal tube two-phase flow according to Embodiment 1 of the present invention.
  • FIG. 10 is a structural diagram of a wet natural gas gas-liquid two-phase flow metering device according to Embodiment 2 of the present invention.
  • the natural gas produced by the gas well 101 is stored and used after being passed through the gas production line 102.
  • An emergency shut-off valve 103 and a shut-off valve 104 are generally disposed on the gas production line 102.
  • the natural gas produced by the gas well 101 is wet natural gas, and the wet natural gas mainly includes a gas phase and a liquid phase.
  • a wet natural gas flow meter 105 is usually disposed on the gas recovery pipeline 102. The gas phase and liquid phase flow rates of the wet natural gas are measured.
  • Embodiments of the present invention provide a wet natural gas gas-liquid two-phase flow metering method, including the following steps:
  • the wet natural gas comprises gas-liquid two phases, and the gas-liquid two phases are filled with interphase momentum, energy and mass exchange during the flow through the orifice plate, and the gas phase and the liquid phase are spatially and temporally distributed. Random.
  • differential pressure noise that is, differential pressure pulsation
  • the differential pressure noise is the difference between the real-time measured value of the differential pressure and the actual value or the measured average value.
  • the traditional measurement theory believes that this noise is the interference to the measurement and is eliminated by filtering.
  • Modern measurement theory considers noise as the inherent physical characteristic of two-phase flow, and is the information carrier of two-phase flow state and parameters. The analysis of the noise mechanism, the statistical filtering model of the noise is established, and the relevant parameters of the two-phase flow can be obtained.
  • the value of the outflow coefficient C can be obtained according to "8.4.2.1” in the standard “Measurement of natural gas flow by standard orifice plate GB/T 21446-2008", and the appendix of the standard can also be adopted if the accuracy requirement is not high.
  • a "Table A.1 Outflow coefficient C value table” lookup table; the value of the expansion coefficient ⁇ can be obtained according to the standard "GB.T. .
  • the method before collecting the differential pressure ⁇ P i before and after the wet natural gas flows through the orifice plate, the method further comprises: collecting the pipeline pressure before the wet natural gas flows through the orifice plate; sampling and testing the wet natural gas, determining the gas phase in combination with the pipeline pressure; Working condition density ⁇ c and liquid phase working density ⁇ d .
  • an orifice plate is used to assist in measuring the flow rate of the wet natural gas, and the pressure of the wet natural gas in the pipeline changes after the wet natural gas flows through the orifice plate, where the wet natural gas flows through the orifice.
  • the line pressure in front of the plate is to facilitate metering the gas phase density and liquid phase density of the wet natural gas.
  • the natural gas component (gas phase) and the produced liquid component (liquid phase) produced by the gas well do not change much in a certain period of time.
  • the density of the liquid phase is basically unaffected by the pressure, it can be obtained by on-site sampling and testing; when the gas phase density is greatly affected by the pressure, the gas density of the standard condition is obtained by sampling analysis, combined with the pressure collected by the pressure transmitter. The gas phase operating density is calculated.
  • the method further comprising: deriving the equation of state of gas by the gas volume flow of wet natural gas, the gas volume flow is calculated according to a liquid phase and a liquid phase density conditions Volume flow.
  • the frequency of the differential pressure ⁇ P i before and after the flow of the wet natural gas through the orifice plate is at least 20 times per second.
  • the method further comprises: collecting the temperature value of the wet natural gas.
  • the temperature value of the wet natural gas is used to calculate the gas phase working density ⁇ c and the liquid phase working density ⁇ d in the foregoing sampling assay, and the temperature value is also used as the parameter of the gas state equation for calculating the gas phase volume flow. .
  • G represents the mass flow rate
  • X represents the mass flow ratio of the phase
  • V represents the volume of the phase
  • Equation 10 shows that the magnitude of the differential pressure square root noise is proportional to the liquid phase flow.
  • Equation 2 Substituting Equation 2 and Formula 3 into Equation 14 yields:
  • Equation 15 shows that when the dispersed phase is a dilute phase, the statistical variance of the differential pressure square root is approximately proportional to the dispersed phase flow. This is identical in form to Equation 10 derived from the perturbation model. In the disturbance model, the discharge of the liquid is random and there is no fixed amplitude. Therefore, in the formula 10 And formula 15 There is no difference in essence, but the method of representation is different. Of course, the statistical model is no longer dependent on the disturbance effect of the barrier, not only for the orifice plate, but also for other throttling devices, or even a set of pipe segments. For convenience, ⁇ is used instead of ⁇ 1 or ⁇ 2 .
  • Equation 3 Substituting Equation 3 into Equation 14 yields:
  • Equation 17 Substituting Equation 17 into Equation 2 gives:
  • Equations 17 and 18 are theoretical models for two-phase flow two-parameter measurement using the statistical mean and relative statistical variance of the two-phase flow differential pressure square of the orifice plate. The form is very simple and the physical meaning is very clear.
  • the first item after the split 18 Is the flow estimate for the continuous phase, where It is a two-phase differential pressure, so this estimate is high.
  • the third item It is a correction to the first high estimate.
  • second section The estimated flow rate for the dispersed phase.
  • Theoretical analysis shows that the ratio of the two-phase flow density and the diameter ratio of the orifice plate may be the influence factors of the proportional coefficient ⁇ , and the two-phase density ratio may be the main factor.
  • the experimental study to determine the proportional coefficient ⁇ and its influencing factors is indispensable for the development of practical empirical models for two-phase flow two-phase flow measurement of orifice plates.
  • the indoor experiment uses a vapor-water two-phase flow.
  • the basic requirement of the experiment of measuring the vapor-water two-phase flow of the orifice plate is to generate a stable two-phase flow of known pressure, temperature and phase flow through the test orifice plate.
  • the device and process are shown in Figure 4, where T 1 and T 2 are first-class standard mercury thermometers, P, P 1 and P 2 are pressure transmitters, and ⁇ P, ⁇ P 1 and ⁇ P 2 are differential pressure transmitters.
  • T 1 and T 2 are first-class standard mercury thermometers
  • P, P 1 and P 2 are pressure transmitters
  • ⁇ P, ⁇ P 1 and ⁇ P 2 are differential pressure transmitters.
  • the steam-water two-phase flow of the direct current boiler (total mass flow, dryness, and pressure adjustable) is used to measure the differential pressure of the vapor-water two-phase flow through the test orifice, and simultaneously measure the pressure at the high pressure side of the orifice before passing through the orifice plate. pressure.
  • the vapor-water two-phase stream then flows through the mixer and is thoroughly mixed with a cold water to form subcooled water (where the flow, pressure and temperature of the supercooled water are metered).
  • All flow metering orifice plates are flanged pressure-standard standard sharp-edged orifice plates designed and processed according to GB-2624-81, and together with their straight pipe sections (upper and downstream ⁇ 30D) are all calibrated by Chongqing Automation, in line with national standards. .
  • Pressure transmitters, differential pressure transmitters (take the 1151 series, time constant 0.2 seconds) and mercury thermometers are required to be qualified after calibration.
  • the test orifice plate is installed horizontally, and the orifice plate dimensions are as follows:
  • Q is the heat loss, which is measured by the experiment and its quantity is extremely small.
  • Two-phase flow of steam and water enthalpy i "and i ', and the enthalpy of cold water, mixed water is i 1' and i 2 'according to their respective pressure and temperature values determined look-up table.
  • the output signals of the pressure transmitter and differential pressure transmitter are metered and printed by a high-precision digital voltmeter with a sampling speed of 20 points/s.
  • G d /F is described (ie, estimating the liquid phase flow by statistical variance), indicating that the liquid phase flow is approximately proportional to the statistical variance of the differential pressure square root of the orifice.
  • the orifice plate has differential pressure noise in the two-phase flow, that is, differential pressure pulsation, which is an inherent characteristic of the two-phase flow, and thus the characteristics of the noise are necessarily related to the two-phase flow.
  • differential pressure pulsation which is an inherent characteristic of the two-phase flow, and thus the characteristics of the noise are necessarily related to the two-phase flow.
  • Fig. 8 the autocorrelation function and linear spectrum of differential pressure noise under three different operating conditions are described. As can be seen from the figure:
  • the autocorrelation function is in the form of ⁇ function, and the linear spectrum has multiple peaks between 0.5-3HZ, which indicates that the differential pressure noise signal is approximately band-limited white noise, and the random distribution law of phase concentration dominates.
  • Figure 10 shows that the a condition is intermittent;
  • the autocorrelation function has a plurality of peaks in addition to one main peak, and there is a distinct main peak on the linear spectrum, indicating that the phase separation effect plays a major role.
  • the two-phase flow belongs to the annular flow (refer to Figure 10), which is consistent with the theoretical assumption of the disturbance model;
  • the c operating condition may be a fog annular flow that transitions from a batch flow to an annular flow.
  • the orifice two-phase flow differential pressure noise is caused by two factors, the separation effect and the random fluctuation of the phase concentration distribution. As the flow conditions change, sometimes the former is the dominant factor, and sometimes the latter plays a major role, sometimes both, and its frequency characteristics change. In fact, even under the annular flow, the "spray" is random and there is no fixed amplitude. Therefore, in data processing, the statistical variance of the differential pressure square root is generally used. In the derivation of the theoretical model, the same conclusion is reached under two different assumptions that do not depend on frequency. In the gas well production process, there is no mechanical vibration, so there is no wavy flow, and the gas produced by the gas well is mainly in the gas phase.
  • the gas-liquid two-phase flow state of the horizontal pipe section in the gas well production process mainly appears misty according to the liquid-gas ratio from small to large.
  • the flow, annular flow, and laminar flow regimes are applicable to the gas-liquid two-phase flow in the horizontal section of the gas well.
  • the gas-liquid two-phase flow can be divided into two types according to the composition of the material.
  • the gas-liquid two-phase flow consisting of two phases of the same component is called a one-component gas-liquid two-phase flow, such as water vapor and water in the experiment.
  • the two-phase flow is composed; the two-phase flow composed of two phases of different components is called a two-component two-phase flow, such as a gas well wet natural gas gas-liquid two-phase flow.
  • the same mathematical model is applied to the one-component gas-liquid two-phase flow and the two-component gas-liquid two-phase flow without phase change. Therefore, the model of Equation 24 is also applicable to the wet natural gas gas-liquid two-phase flow metering, that is, the metering method model of the embodiment of the present invention.
  • the wet natural gas flow metering method provided by the embodiment of the invention collects the differential pressure before and after the flow of the wet natural gas through the orifice plate, and combines the multiphase flow calculation algorithm to realize the real-time on-line measurement of the gas production and the liquid production volume without separation.
  • Relatively simple The method is simple and cost-effective.
  • the theoretical mathematical model derivation and experimental verification are respectively performed for the two-phase flow of the plurality of flow patterns, so that the measurement method provided by the embodiment is more rigorous and accurate.
  • an embodiment of the present invention further provides a wet natural gas gas-liquid two-phase flow metering device, which uses the method as described in Embodiment 1 to measure a gas-liquid two-phase flow rate of wet natural gas, and the device includes:
  • the differential pressure collecting unit 20 is configured to collect the differential pressure ⁇ P i of the wet natural gas flowing through the orifice plate multiple times in a predefined period;
  • the flow calculation unit 21 is configured to calculate the liquid phase mass flow rate G d and the gas phase mass flow rate G c based on the following formula:
  • the apparatus further includes: a pressure collecting unit 22, configured to collect the pipeline pressure before the wet natural gas flows through the orifice plate before collecting the differential pressure ⁇ P i before and after the wet natural gas flows through the orifice plate; the density calculation unit 23, for sampling and testing wet natural gas, combined with pipeline pressure to obtain gas phase density ⁇ c and liquid phase density ⁇ d .
  • the flow calculation unit 21 is further configured to: after calculating the liquid phase mass flow rate G d and the gas phase mass flow rate G c , deriving the gas phase volume flow rate of the wet natural gas by the gas state equation, according to the gas phase volume flow rate and the liquid phase working density Calculate the liquid volume flow rate.
  • the differential pressure collecting unit 20 collects the differential pressure ⁇ P i of the wet natural gas before and after flowing through the orifice plate to at least 20 times per second.
  • the apparatus further includes: a temperature collecting unit 24 configured to collect the temperature value of the wet natural gas before collecting the differential pressure ⁇ P i before and after the wet natural gas flows through the orifice plate.
  • the wet natural gas flow metering device collects the differential pressure before and after the wet natural gas flows through the orifice plate by using the differential pressure collecting unit, and uses the flow calculating unit to combine the multiphase flow algorithm to realize the gas production amount and the liquid production amount.
  • the real-time online measurement is not separated, and the measurement method is relatively simple and low in cost.

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Abstract

一种湿天然气气液两相流量计量装置，包括：差压采集单元（20），用于在预定周期内多次采集湿天然气流经节流孔板前后的差压；流量计算单元（21），用于计算液相质量流量以及气相质量流量。通过多次采集湿天然气流经节流孔板前后的差压，结合多相流计算算法实现了产气量、产液量的不分离实时在线计量。

Description

一种湿天然气气液两相流量计量装置 技术领域
本发明涉及流体流量测量技术领域，特别涉及一种湿天然气气液两相流量计量方法及计量装置。
背景技术
天然气生产过程中，气井产气量、产液量是气田生产、管理的重要数据之一，既是制定生产工艺、确定生产流程和生产管理方式的重要依据，也是优化气田配产、确保气藏合理开采的基础数据。
随着天然气工业的迅猛发展，国内外相关机构开始研究湿天然气气液两相不分离在线计量技术，并取得的重大进展。纵观国内外湿天然气气液两相在线计量技术，主要采用以下两种计量方法，一是采用两种或多种单量流量计串联组合，根据单相流量计对湿天然气计量的虚高特性，建立两个或多个关系式，联立求解得出气液两相流量；二是采用单量流量计结合微波、射线等技术得出气液两相流量。
上述两种计量方法均存在成本高昂的问题，并且主要应用于国外海洋、沙漠等大产量气井的湿天然气计量，无法满足国内气井产量普遍较低、要求开发成本较低的情况，不适应国内的商业应用环境。
发明内容
为了解决现有技术中湿天然气气液两相在线计量方法成本高昂、无法满足国内气井产量情况且不适应国内商业应用环境的问题，本发明实施例提供了一种湿天然气气液两相流量计量方法及计量装置，技术方案如下：
一方面，本发明实施例提供了一种湿天然气气液两相流量计量方法，一种湿天然气气液两相流量计量方法，其特征在于，所述方法包括：
在预定义周期内多次采集湿天然气流经节流孔板前后的差压△Pi，
基于以下公式计算液相质量流量Gd以及气相质量流量Gc：
Figure PCTCN2016080894-appb-000001
其中，
Figure PCTCN2016080894-appb-000002
为差压方根的统计平均值，
Figure PCTCN2016080894-appb-000003
为统计方差，R为相对统计方差，ρc为气相工况密度，ρd为液相工况密度，θ为经验常数，Xd为液相质量含量比份，G为天然气总质量流量，C为节流孔板的流出系数，β为节流装置孔径比，d为孔板孔径，D为计量管内径，ε为所述湿天然气的可膨胀系数。
进一步地，在所述采集湿天然气流经节流孔板前后的差压△Pi前，所述方法还包括：采集湿天然气流经节流孔板前的管线压力；取样化验所述湿天然气，结合所述管线压力确定气相工况密度ρc和液相工况密度ρd。
进一步地，在所述计算液相质量流量Gd以及气相质量流量Gc之后，所述方法还包括：通过气体状态方程推导出所述湿天然气的气相体积流量，根据所述气相体积流量及所述液相工况密度计算液相体积流量。
较佳地，所述采集湿天然气流经节流孔板前后的差压△Pi的频率为每秒至少20次。
进一步地，在所述采集湿天然气流经节流孔板前后的差压△Pi前，所述方法还包括：采集所述湿天然气的温度值。
另一方面，本发明实施例还提供一种湿天然气气液两相流量计量装置，所述装置包括：
差压采集单元，用于在预定义周期内多次采集湿天然气流经节流孔板前后的差压△Pi；
流量计算单元，用于基于以下公式计算液相质量流量Gd以及气相质量流量Gc：
Figure PCTCN2016080894-appb-000004
其中，
Figure PCTCN2016080894-appb-000005
为差压方根的统计平均值，
Figure PCTCN2016080894-appb-000006
为统计方差，R为相对统计方差，ρc为气相工况密度，ρd为液相工况密度，θ为经验常数，Xd为液相质量含量比份，G为天然气总质量流量，C为节流孔板的流出系数，β为节流装置孔径比，d为孔板孔径，D为计量管内径，ε为所述湿天然气的可膨胀系数。
进一步地，所述装置还包括：压力采集单元，用于在所述采集湿天然气流经节流孔板前后的差压△Pi前，采集湿天然气流经节流孔板前的管线压力；密度计算单元，用于取样化验所述湿天然气，结合所述管线压力确定气相工况密度ρc和液相工况密度ρd。
进一步地，所述流量计算单元还用于：在所述计算液相质量流量Gd以及气相质量流量Gc之后，通过气体状态方程推导出所述湿天然气的气相体积流量，根据所述气相体积流量及所述液相工况密度计算液相体积流量。
较佳地，所述差压采集单元采集湿天然气流经节流孔板前后的差压△Pi的频率为每秒至少20次。
进一步地，所述装置还包括：温度采集单元，用于在所述采集湿天然气流经节流孔板前后的差压△Pi前，采集所述湿天然气的温度值。
本发明实施例提供的技术方案的有益效果是：
通过多次采集湿天然气流经节流孔板前后的差压，结合多相流计算算法实现了产气量、产液量的不分离实时在线计量，计量方法相对简单且成本较低。
附图说明
下面将结合附图及实施例对本发明作进一步说明，附图中：
图1是本发明实施例提供的应用场景图；
图2是本发明实施例1提供的两相流在孔板上的相分离效应图；
图3是本发明实施例1提供的一种环状流型的两相流的液相流量模型图；
图4是本发明实施例1提供的汽—水两相流实验***原理图；
图5是本发明实施例1提供的液相流量与孔板差压方根的统计方差的关系图；
图6是本发明实施例1提供的
Figure PCTCN2016080894-appb-000007
跟差压方根相对统计方差R的关系图；
图7是本发明实施例1提供的
Figure PCTCN2016080894-appb-000008
跟
Figure PCTCN2016080894-appb-000009
的关系图；
图8是本发明实施例1提供的三种工况下差压噪声的自相关函数图和线性频谱图。
图9是本发明实施例1提供的水平管两相流的基本流型图；
图10是本发明实施例2提供的一种湿天然气气液两相流量计量装置结构图。
具体实施方式
为使本发明的目的、技术方案和优点更加清楚，下面将结合附图对本发明实施方式作进一步地详细描述。
下面先简单介绍一下本发明实施例的应用场景。参见图1，通过气井101产出的天然气流经采气管线102后被存储使用，在采气管线102上通常会设置紧急截断阀103以及截止阀104。气井101产出的天然气为湿天然气，湿天然气中主要包括气相和液相两部分，为了制定生产工艺、确定生产流程和生产管理方式，通常需要在采气管线102上设置湿天然气流量计105，对湿天然气的气相和液相流量进行计量。
需要说明的是，以上所述的设备种类、连接关系和连接方式仅为举例，本发明对此不作限制。
实施例1
本发明实施例提供了一种湿天然气气液两相流量计量方法，包括以下步骤：
S1：在预定义周期内多次采集湿天然气流经节流孔板前后的差压△Pi；
具体地，湿天然气包含气液两相，气液两相在流经节流孔板的流动过程中充满了相间的动量、能量及质量交换，其气相和液相分布在空间上和时间上是随机的。两相流通过节流孔板时存在着差压噪声，即差压脉动，差压噪声为差压实时测量值与真实值或测量平均值之差。传统的计量理论认为这一噪声是对计量的干扰，并通过滤波而加以消除；现代计量理论认为噪声是两相流流动的固有物理特征，是两相流流动状态和参数的信息载体，通过对噪声机理的分析，建立噪声的统计滤波模型，可以得到两相流的相关参数。
S2：基于以下公式计算液相质量流量Gd以及气相质量流量Gc：
Figure PCTCN2016080894-appb-000010
其中，
Figure PCTCN2016080894-appb-000011
为差压方根的统计平均值，
Figure PCTCN2016080894-appb-000012
为统计方差，R为相对统计方差，ρc为气相工况密度，ρd为液相工况密度，θ为经验常数，Xd为液相质量含量比份，G为天然气总质量流量，C为节流孔板的流出系数，β为节流装置孔径比，d为孔板孔径，D为计量管内径，ε为湿天然气的可膨胀系数。
具体地，流出系数C的值可以按照标准《GB/T 21446-2008用标准孔板测量天然气流量》中“8.4.2.1”处求得，在精度要求不高情况下也可通过该标准中附录A“表A.1流出系数C值表”查表得出；可膨胀系数ε的值可以按照标准《GB/T 21446-2008用标准孔板测量天然气流量》中“8.4.2.5”处求得。
进一步地，在采集湿天然气流经节流孔板前后的差压△Pi前，该方法还包括：采集湿天然气流经节流孔板前的管线压力；取样化验湿天然气，结合管线压力确定气相工况密度ρc和液相工况密度ρd。
具体地，本实施例中使用了节流孔板来辅助计量湿天然气的流量，湿天然气流过节流孔板后管线中的湿天然气的压力会产生变化，此处采集湿天然气流经节流孔板前的管线压力是为了便于计量湿天然气的气相工况密度和液相工况密度。
具体地，对于某一区域的气井，气井采出的天然气组分(气相)和产出液组分(液相)在一定时间内变化不大。因为液相工况密度基本不受压力影响，可通过现场取样化验得出；气相工况密度受压力影响较大，则通过取样分析得出标况气相密度，结合压力变送器采集的压力，计算出气相工况密度。
进一步地，在计算液相质量流量Gd以及气相质量流量Gc之后，该方法还包括：通过气体状态方程推导出湿天然气的气相体积流量，根据气相体积流量及液相工况密度计算液相体积流量。
较佳地，采集湿天然气流经节流孔板前后的差压△Pi的频率为每秒至少20次。
进一步地，在采集湿天然气流经节流孔板前后的差压△Pi前，该方法还包括：采集湿天然气的温度值。
具体地，湿天然气的温度值用于在前述取样化验过程中计算气相工况密度ρc和液相工况密度ρd，同时，该温度值还作为前述计算气相体积流量的气体状态方程的参数。
上述计量湿天然气气液两相流量的相关公式需要进行理论模型的推导和实验验证，具体过程如下：
一、建立气液两相流量计量的理论数学模型
1、两相分离流理想模型
采用孔板计量单相流流量的公式为：
Figure PCTCN2016080894-appb-000013
在气液两相流动中，假设：两相分别流过孔板，相间无动量交换、无相变过程，并且满足绝热条件，由此可以得出孔板两相分离流的理想模型：
Figure PCTCN2016080894-appb-000014
Figure PCTCN2016080894-appb-000015
Figure PCTCN2016080894-appb-000016
其中，G表示质量流量，X表示相的质量流量比份，V表示相的体积。
所谓理想模型，是指在上述假设条件下，完全忽略两相流存在的“滑移”现象，但实际上是不可能不存在的。
2、扰动模型
在气液两相流动中，假设：两相流以环状流流过孔板；如图2所示，气相自由流动，液相被孔板阻滞、累积、然后喷放；如图3所示，气相中不含有液滴，在阻滞、累积阶段没有液相流过孔板，累积的液体以脉冲形式喷放。则液相瞬态脉冲为GdP＝GdT/τ。在液相被阻滞时，只有气相流过孔板，则有：
Figure PCTCN2016080894-appb-000017
当液相流过孔板时：
Xcp＝Gc/(Gc+Gcp)＝1/(1+T/τ·Xd)      (式6)
在无动量交换条件下有：
Figure PCTCN2016080894-appb-000018
由式(5-2)，(5-4)及(5-5)得：
Figure PCTCN2016080894-appb-000019
式中
Figure PCTCN2016080894-appb-000020
分别为差压方根的峰值和谷值，定为差压方根脉动幅值：
Figure PCTCN2016080894-appb-000021
定义表征相分离效应的相分离系数θ1＝T/(2τ)，则得：
Figure PCTCN2016080894-appb-000022
式10表明差压方根噪声幅值正比于液相流量。
3、统计模型
除上述两种假设的模型外，假设：分散相(稀相，此处为液相)浓度分布的统计方差正比于该相平均相浓度；在充分发展的两相流动中，连续相(此处为气相)的流量恒定，这在分散相为稀相时近似成立。于是
Figure PCTCN2016080894-appb-000023
可以看作为一个恒量，由式4得随机变量计量差压△P(t)和分散相浓度Vd(t)的关系：
Figure PCTCN2016080894-appb-000024
考虑到相对波动较小，△P(t)和Vd(t)的统计方差可由下式近似：
Figure PCTCN2016080894-appb-000025
将式12代入式得：
Figure PCTCN2016080894-appb-000026
考虑到液相为稀相，1-Vd≈1，则由假设σ(Vd)＝θ2·Vd，可得：
Figure PCTCN2016080894-appb-000027
将式2、式3代入式14，得：
Figure PCTCN2016080894-appb-000028
式15表明，分散相为稀相时，差压方根的统计方差近似正比于分散相流量。这同由扰动模型得出的式10在形式上完全一致。在扰动模型中，液体的喷放是随机的，不存在某一固定幅值。因此，式10中的
Figure PCTCN2016080894-appb-000029
和式15中
Figure PCTCN2016080894-appb-000030
在本质上并无区别，只是表征方法不同。当然，统计模型的情况不再依赖阻挡体的扰动效应，不仅适用于孔板，也适用于其他节流装置，甚至是一组管段。为方便起见，下文用θ代替θ1或θ2。
4、孔板差压噪声计量气液两相双参数理论模型
定义：计量差压方根的相对统计方差为：
Figure PCTCN2016080894-appb-000031
将式3代入式14得：
Figure PCTCN2016080894-appb-000032
将式17代入式2得：
Figure PCTCN2016080894-appb-000033
式17和式18是利用孔板两相流差压方根的统计平均值和相对统计方差进行两相流双参数计量的理论模型。其形式非常简单，物理意义也十分清晰。式18拆开后的第一项
Figure PCTCN2016080894-appb-000034
为连续相的流量估计值，其中
Figure PCTCN2016080894-appb-000035
为两相差压，所以这一估计值偏高。第三项
Figure PCTCN2016080894-appb-000036
是对第一项偏高估计的修正。第二项
Figure PCTCN2016080894-appb-000037
为分散相的流量估计值。
理论分析表明：两相流密度比、孔板的直径比等都可能是比例系数θ的影响因子，而两相密度比可能是主要因素。通过实验研究确定比例系数θ及其影响因素，对于发展孔板两相流双参数计量的实用经验模型是必不可少的。
(二)孔板差压噪音计量理论模型实验验证
1、实验***描述
室内实验采用汽-水两相流进行，孔板计量汽—水两相流的实验的基本要求是产生一股已知压力、温度和相流量的稳定两相流流经试验孔板，其实验装置及流程如图4所示，其中T1、T2为一等标准水银温度计，P、P1、P2为压力变送器，△P、△P1、△P2为差压变送器。采用直流锅炉的汽—水两相流(总质量流量、干度、压力可调)，计量汽—水两相流经过试验孔板时差压，同时计量经过孔板前的高压侧取压口处的压力。然后汽—水两相流会流经混合器，与一股冷水充分混合，形成过冷水(在此计量过冷水的流量、压力和温度)后排出。
所有流量计量孔板为按国标GB－2624－81设计、加工的法兰取压标准锐边孔板，并连同其直管段(上、下游均≥30D)均由重庆自动化所标定，符合国家标准。压力变送器、差压变送器(取1151系列，时间常数0.2秒)以及水银温度计均需标定合格后采用。试验孔板水平安装，其孔板尺寸如下表所示：
Figure PCTCN2016080894-appb-000038
流经试验孔板的汽—水两相流(饱和水蒸汽)的质量流量和干度按连续性方程和能量平衡方程得出：
G＝G2-G1      (式19)
Xc＝(G2i2′-G1i1′-(G2-G1)i′+Q)/((G2-G1)(i″-i′))      (式20)
式中，Q为热损失，由实验计量，其数量极小。两相流的汽、水焓i″和i′、以及冷水、混合水的焓为i1′和i2′根据各自压力和温度值查表求出。
压力变送器和差压变送器的输出信号由高精度的数字电压表计量并打印记录，其采样速度为20点/s。
对于上表中6种不同尺寸的孔板，在不同的压力、流量和干度工况下进行试验。其实验参数范围为：运行压力：0.58—12.1MPa；干度：0.05—0.95；流量：1580—7400Kg/h；
设
Figure PCTCN2016080894-appb-000039
为差压方根采样值，则孔板两相流差压方根的统计平均值
Figure PCTCN2016080894-appb-000040
统计方差
Figure PCTCN2016080894-appb-000041
相对统计方差R由式21、式22、式23计算：
Figure PCTCN2016080894-appb-000042
Figure PCTCN2016080894-appb-000043
Figure PCTCN2016080894-appb-000044
实验过程中，调整好锅炉出口流量(通过调节给水量)和干度(通过调节给油量)，并调节冷水流量，以确保混合后的水为过冷水。但是过冷度不能太低，否则两相流量误差会增大。
2、实验结果及分析
(1)实验结果
如图5所示，描述了Gd/F跟
Figure PCTCN2016080894-appb-000045
(即由统计方差估计液相流量)的关系，表明液相流量近似正比于孔板差压方根的统计方差。
如图6所示，描述了
Figure PCTCN2016080894-appb-000046
跟差压方根相对统计方差R(即式17)的关系。
如图7所示，描述了
Figure PCTCN2016080894-appb-000047
跟
Figure PCTCN2016080894-appb-000048
(即式18)的关系。
从实验数据和图5至图7可以看出：
①实验数据同理论模型符合良好；
②两相密度比、孔板直径比等因素对θ值的影响不明显；
③取实验数据θ的平均值，作为实用模型的比例系数，则估计流量和干度的均方偏差分别为9.0％和6.5％。这一误差，同现有各种组合式两相流计量方法的误差相当；
④理论推导中假设1-Vd≈1，图中可见低干度时偏离直线较远，这同理论分析一致。
(2)模型分析
孔板在两相流中存在差压噪声，即差压脉动，这是两相流动的固有特性，因而噪声的特点必然与两相流动有关。如图8所示，描述了3种不同工况下差压噪声的自相关函数和线性频谱。从图中可以看出：
①a工况上，自相关函数呈δ函数状，线性谱在0.5-3HZ之间有多个峰，这表明差压噪声信号近似为限带白噪声，相浓度的随机分布规律起支配作用。图10中表明a工况为间歇状流；
②b工况下，自相关函数除了有一主峰外，还有多个峰，而在线性谱上有一明显的主峰，表明相分离效应起主要作用。此时两相流属环状流(参考图10)，同扰动模型的理论假设一致；
③c工况下，自相关函数和线性谱界于a、b之间，相分离和随机性同时起作用。参考图9，c工况可能是由间歇状流过渡到环状流的雾环状流。
孔板两相流差压噪声是由分离效应和相浓度分布的随机波动两种因素引起的。随着流动工况的改变，有时前者是支配因素，有时后者起主要作用，有时两者兼而有之，而且其频率特性也随之而变。实际上，即使在环状流下，“喷放”也是随机的，并不存在某一固定不变的幅值。因此，在数据处理时，一般采用差压方根的统计方差。理论模型的推导中，在不依赖频率的两种不同假设条件下，得出了相同的结论。气井生产过程中，不存在机械振动，所以不存在波状流，且气井产出流体以气相为主，所以气井生产过程中水平管段气液两相流态根据液气比从小到大主要出现雾状流、环状流、层流三种流态，因此该理论适用于气井水平管段气液两相流。
根据上述理论分析和实验验证，可得出如下实用经验模型：
Figure PCTCN2016080894-appb-000049
气液两相流按物质组分的不同可分为两种，由同一组分的两相组成的气液两相流称为单组分气液两相流，如实验中的水蒸气和水构成的两相流；由不同组分的两相组成的两相流称为双组分两相流，如气井湿天然气气液两相流。在不发生相变时，单组分的气液两相流和双组分的气液两相流适用同样的数学模型。因此，式24模型也适用于湿天然气气液两相流量计量，即本发明实施例的计量方法模型。
本发明实施例提供的湿天然气流量计量方法通过多次采集湿天然气流经节流孔板前后的差压，结合多相流计算算法实现了产气量、产液量的不分离实时在线计量，计量方法相对简 单且成本较低，同时本实施例针对多种流型的两相流分别做出理论数学模型推导以及实验验证，使得本实施例提供的计量方法更具严谨性和准确性。
实施例2
如图10所示，本发明实施例还提供一种湿天然气气液两相流量计量装置，采用如实施例1所述的方法来计量湿天然气的气液两相流量，该装置包括：
差压采集单元20，用于在预定义周期内多次采集湿天然气流经节流孔板前后的差压△Pi；
流量计算单元21，用于基于以下公式计算液相质量流量Gd以及气相质量流量Gc：
Figure PCTCN2016080894-appb-000050
其中，
Figure PCTCN2016080894-appb-000051
为差压方根的统计平均值，
Figure PCTCN2016080894-appb-000052
为统计方差，R为相对统计方差，ρc为气相工况密度，ρd为液相工况密度，θ为经验常数，Xd为液相质量含量比份，G为天然气总质量流量，C为节流孔板的流出系数，β为节流装置孔径比，d为孔板孔径，D为计量管内径，ε为湿天然气的可膨胀系数。
进一步地，该装置还包括：压力采集单元22，用于在采集湿天然气流经节流孔板前后的差压△Pi前，采集湿天然气流经节流孔板前的管线压力；密度计算单元23，用于取样化验湿天然气，结合管线压力获取气相工况密度ρc和液相工况密度ρd。
进一步地，流量计算单元21还用于：在计算液相质量流量Gd以及气相质量流量Gc之后，通过气体状态方程推导出湿天然气的气相体积流量，根据气相体积流量及液相工况密度计算 液相体积流量。
较佳地，差压采集单元20采集湿天然气流经节流孔板前后的差压△Pi的频率为每秒至少20次。
进一步地，该装置还包括：温度采集单元24，用于在采集湿天然气流经节流孔板前后的差压△Pi前，采集湿天然气的温度值。
本发明实施例提供的湿天然气流量计量装置通过使用差压采集单元多次采集湿天然气流经节流孔板前后的差压，使用流量计算单元结合多相流算法实现了产气量、产液量的不分离实时在线计量，计量方法相对简单且成本较低。
以上所述仅为本发明的较佳实施例，并不用以限制本发明，凡在本发明的精神和原则之内，所作的任何修改、等同替换、改进等，均应包含在本发明的保护范围之内。

Claims (5)

  1. 一种湿天然气气液两相流量计量装置，其特征在于，所述装置包括：
    差压采集单元，用于在预定义周期内多次采集湿天然气流经节流孔板前后的差压△Pi；
    流量计算单元，用于基于以下公式计算液相质量流量Gd以及气相质量流量Gc：
    Figure PCTCN2016080894-appb-100001
    其中，
    Figure PCTCN2016080894-appb-100002
    为差压方根的统计平均值，
    Figure PCTCN2016080894-appb-100003
    为统计方差，R为相对统计方差，ρc为气相工况密度，ρd为液相工况密度，θ为经验常数，Xd为液相质量含量比份，G为天然气总质量流量，C为节流孔板的流出系数，β为节流装置孔径比，d为孔板孔径，D为计量管内径，ε所述湿天然气的为可膨胀系数。
  2. 根据权利要求1所述的装置，其特征在于，所述装置还包括：
    压力采集单元，用于在所述采集湿天然气流经节流孔板前后的差压△Pi前，采集湿天然气流经节流孔板前的管线压力；
    密度计算单元，用于取样化验所述湿天然气，结合所述管线压力确定气相工况密度ρc和液相工况密度ρd。
  3. 根据权利要求1所述的装置，其特征在于，所述流量计算单元还用于：
    在所述计算液相质量流量Gd以及气相质量流量Gc之后，通过气体状态方程推导出所述湿天然气的气相体积流量，根据所述气相体积流量及所述液相工况密度计算液相体积流量。
  4. 根据权利要求1所述的装置，其特征在于，所述差压采集单元采集湿天然气流经节流 孔板前后的差压△Pi的频率为每秒至少20次。
  5. 根据权利要求1-4任一项所述的装置，其特征在于，所述装置还包括：
    温度采集单元，用于在所述采集湿天然气流经节流孔板前后的差压△Pi前，采集所述湿天然气的温度值。
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