CN112710703B - Three-phase flow imaging method of conductive grid sensor with conductive characteristic compensation - Google Patents
Three-phase flow imaging method of conductive grid sensor with conductive characteristic compensation Download PDFInfo
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Abstract
The invention provides a conductive grid sensor three-phase flow imaging method with conductive characteristic compensation, wherein a measuring pipeline is a vertically upward pipeline, three-phase flow is oil-gas-water three-phase flow, and adopted sensors are a conductive grid sensor and a distributed coaxial conductive sensor; the electric conduction grid sensor comprises an exciting electrode and a receiving electrode, the electric conduction grid sensor adopts a circulation exciting mode, and after one circulation exciting is completed, the electric conduction grid sensor outputs one frame of data corresponding to one image of gas phase distribution in the oil-gas-water three-phase flow. The distributed coaxial conductivity sensor comprises three coaxial conductivity sensors; the three coaxial conductivity sensors are uniformly arranged around the same radial section of the measuring pipeline, and the front end of each coaxial conductivity sensor is provided with a liquid extension area which is designed to be inclined upwards and form an included angle of 30 degrees with the radial section of the measuring pipeline.
Description
Technical Field
The invention relates to a three-phase flow imaging method of a conductive grid sensor with conductive characteristic compensation.
Background
The flow phenomenon of oil-gas-water three-phase flow widely exists in the production process of petroleum, chemical industry and other important industries. The accurate measurement of the oil-gas-water gas holdup rate has important significance for production safety and economic benefit improvement. However, most multiphase flow measurement systems are designed based on a single measurement mode, such as dielectric constant or conductivity, which has significant limitations for complex oil, gas, and water three-phase flow measurements.
At present, the method widely used for measuring the flow parameters of the three-phase flow is bimodal measurement, namely two physical properties of the three-phase flow are measured simultaneously to distinguish three different media. Qiu et al (Flow Measurement & Instrumentation,2007,18: 247-. However, this type of system is not suitable for measuring multiphase mixed fluids with a strongly evolving structure, since the two sensors are placed at different locations of the pipe. Sun et al (Measurement,2015,6: 150-. In addition, because ECT itself is used as a soft measurement scheme, higher spatial resolution cannot be achieved, and its use also has certain limitations.
The conductive grid sensor as an emerging fluid visualization technology has certain advantages in the aspect of researching flow parameters of complex multiphase flow. The sensor was originally proposed by Prasser et al (Flow Measurement & Instrumentation,1998,9(2): 111-. The conductivity grid sensor is sensitive to the change of the conductivity at the intersection point of the two layers of electrodes, so that the measurement of a gas-liquid or oil-water two-phase flow structure and the local phase separation holding rate can be realized. Previous scholars have primarily utilized conductive grid sensors to measure flow parameters in two-phase flow. In recent years, researchers have applied two excitation signals of different frequencies to a grid sensor to achieve simultaneous Measurement of resistance and capacitance at the intersection, but at present this solution is only suitable for simple testing of stratified flow of oil, gas and water three-phase flow under static experimental conditions (Measurement Science & Technology,2015,26: 105302).
FIG. 1 is a schematic diagram of a typical gas-liquid two-phase flow and oil-gas-water three-phase flow pipeline radial cross-section phase distribution. According to the typical phase distribution of the gas-liquid two-phase flow shown in fig. 1(a), when only two media, namely gas and water, exist in the pipeline, the gas mainly exists in two forms: dispersed air bubbles and taylor bubbles of larger size, like bullets. Oil-gas-water three-phase flow can be divided into two types according to different continuous phases: firstly, water is a continuous phase (figure 1 (b)); secondly, the low oil content oil-water emulsion is a continuous phase (fig. 1 (c)). For the case of fig. 1(b), since the oil droplet size is much smaller than the spatial resolution of the grid sensor, the dispersed oil droplets do not affect the measurement of the gas holdup by the conductive grid sensor. For the situation shown in fig. 1(c), when the oil-water emulsion is in the continuous phase, the oil content affects the conductivity of the continuous liquid phase, so that the conductive grid sensor cannot accurately measure the gas holdup, and an effective real-time monitoring means for the conductivity of the oil-water emulsion and an effective method for correcting the measurement response of the grid sensor are required.
Disclosure of Invention
The invention provides a three-phase flow imaging method of a conductive grid sensor with conductive characteristic compensation. A combined measuring system of a conductivity grid sensor and a coaxial conductivity sensor is designed, the coaxial conductivity sensor adopts a special distributed non-invasive structure, and can monitor the conductivity of a continuous phase (oil-water emulsion) in an oil-gas-water three-phase flow in real time, so that the imaging result of the gas phase distribution in the oil-gas-water three-phase flow of the conductivity grid sensor is corrected, and finally, accurate oil-gas-water three-phase flow visualization imaging is obtained. The technical scheme is as follows:
a three-phase flow imaging method of a conductive grid sensor with conductive characteristic compensation is characterized in that a measuring pipeline is a vertically upward pipeline, three-phase flows are oil-gas-water three-phase flows, one of the adopted sensors is the conductive grid sensor, and the other sensor is a distributed coaxial conductive sensor; the conductivity grid sensor comprises excitation electrodes and receiving electrodes, wherein the excitation electrodes are parallel to each other and are positioned on the same radial section of the measuring pipeline, the receiving electrodes are parallel to each other and are positioned on the other radial section of the measuring pipeline, the conductivity grid sensor adopts a circulating excitation mode, and after one-time circulating excitation is completed, the conductivity grid sensor outputs one frame of data corresponding to one image of gas phase distribution in the oil-gas-water three-phase flow. The distributed coaxial conductivity sensor is used for dynamically monitoring the change of continuous phase conductivity characteristics and realizing the real-time correction of the imaging result of the conductivity grid sensor, and comprises three coaxial conductivity sensors; the three coaxial conductivity sensors are uniformly arranged around the same radial section of the measuring pipeline, and the front end of each coaxial conductivity sensor is provided with a liquid continuation area which is designed to be inclined upwards and form an included angle of 30 degrees with the radial section of the measuring pipeline; the method for imaging the oil-gas-water three-phase flow by using the conductive grid sensor and the coaxial conductive sensor comprises the following steps:
1) aiming at oil-gas-water three-phase flow, obtaining output signal V of electric conduction grid sensorm,1,Vm,2,…,Vm,10And a marking signal VMarkFor the k frame data, at VMarkCalculating the jth receiving electrode signal V in the time interval between two adjacent rising edgesm,j(k) The extreme difference of (D) is marked as Vm(i, j, k), wherein i is the excitation electrode number;
2) filling air into the measuring pipeline, and measuring output signal V of the electric conductance grid sensorg,1,Vg,2,…,Vg,10To V pairg,1,Vg,2,…,Vg,10Processing to obtain the range Vg(i, j, k); calculating air phase range V under different data framesgAverage value V of (i, j, k)g(i,j)；
3) Filling the measuring pipeline with water phase, and measuring output signal V of the electric conductance grid sensorw,1,Vw,2,…,Vw,10(ii) a To Vg,1,Vg,2,…,Vg,10Processing to obtain range difference signal Vw(i, j, k); calculating the phase range V of different data frameswAverage value V of (i, j, k)w(i,j)；
4) From the results in steps 1), 2) and 3), on signal Vm(i, j, k) carrying out normalization processing to obtain normalized signal
Wherein N is the number of frames; 5) obtaining a measurement signal U of a distributed coaxial conductivity sensor aiming at oil-gas-water three-phase flowm,1，Um,2，Um,3For the k frame data, the average value U of the p, p is 1,2,3, coaxial conductivity sensor measurement signals is calculatedm,p(k)；
6) Filling air into the measuring pipeline to obtain a measuring signal U of the distributed coaxial conductivity sensorg,1，Ug,2，Ug,3(ii) a Calculating the average value U of the measurement signal of the No. p coaxial conductivity sensorg,p(k) (ii) a Then, calculating U under different data framesg,p(k) Average value of Ug,p；
7) Filling the measuring pipeline with water phase to obtain a measuring signal U of the distributed coaxial conductivity sensorw,1，Uw,2，Uw,3(ii) a Calculating the average value U of the measurement signal of the No. p coaxial conductivity sensorw,p(k) Then calculating U under different data framesw,p(k) Average value of Uw,p；
8) For the normalized signal V obtained in step 4)N(i, j, k) performing a correction: calculating the conductivity correction coefficient of a single coaxial conductivity sensor to the continuous phase in the oil-gas-water three-phase flow
Calculating an average value delta (k) of the three conductivity correction coefficients; obtaining a normalized signal VN(i, j, k) correction results
9) According to the correction result of step 8), for
And carrying out bicubic spline interpolation operation to obtain an imaging result of gas-phase distribution of the oil-gas-water three-phase flow.
Due to the adoption of the technical scheme, the invention has the following advantages:
(1) the invention provides a novel distributed non-invasive structure of a coaxial conductivity sensor, aiming at a flow structure of vertical oil-gas-water three-phase flow. Based on the distributed non-invasive structure, the coaxial conductivity sensor can monitor the change of the conductive property of the continuous phase in the oil-gas-water three-phase flow in real time.
(2) The invention provides a real-time correction method for a gas-phase distribution imaging result of a conductive grid sensor based on the continuous phase conductive characteristic of an oil-gas-water three-phase flow measured by a coaxial conductive sensor, which can effectively improve the imaging precision of the conductive grid sensor on the gas-phase distribution of the oil-gas-water three-phase flow.
Drawings
FIG. 1 is a schematic view of the radial cross-section phase distribution of a vertical rising gas-liquid two-phase flow and a typical oil-gas-water three-phase flow pipeline
FIG. 2 is a schematic diagram of an oil-gas-water three-phase flow gas phase distribution imaging system: (a) a conductive grid sensor structure diagram; (b) a front view and a side view of the coaxial conductivity sensor; (c) a piping installation schematic of a single coaxial conductivity sensor; (d) pipeline installation diagrams of three distributed coaxial conductivity sensors; (e) pipeline installation diagram of the conductivity grid sensor and the coaxial conductivity sensor.
FIG. 3 is a schematic diagram of output signals of a conductivity grid sensor and distributed coaxial conductivity sensors
FIG. 4 is a flow chart of conductance grid sensor output signal processing
FIG. 5 is a flow chart of distributed coax conductance sensor output signal processing
FIG. 6 shows output signals of oil-gas-water three-phase flow distributed coaxial conductivity sensor
FIG. 7 is the process of the conductivity grid sensor to image the gas phase distribution of the oil-gas-water three-phase flow
FIG. 8 is the three-dimensional imaging result (U) of the gas phase distribution in the three-phase flow of oil, gas and water by the conductive grid sensorsg＝0.055m/s，Usl＝1.179m/s)：(a)fo0.05, uncorrected; (b) f. ofo0.05, correcting; (c) f. ofo0.15, uncorrected; (d) f. ofo0.15, correction
The reference numerals are explained below:
1 a circular central excitation electrode; 2 an intermediate insulating material; 3 an outer annular receiving electrode; 4 a fluid continuation zone; 5, pipe wall; 6 is perpendicular to the central axis of the pipeline.
Detailed Description
The invention is described in detail below with reference to the figures and examples. The invention includes:
(1) the sensing system is designed as shown in fig. 2. The system includes a conductive grid sensor, a distributed coaxial conductivity sensor, and a measurement circuit. Grid sensor with excitation electrode (E)1To E10) And a receiving electrode (R)1To R10) Composition, as shown in FIG. 2 (a). All the excitation electrodes are parallel to each other and are positioned on the same radial section of the pipeline; the receiving electrodes are parallel to each other and are located at the other radial section of the pipeline. The sensor adopts a cyclic excitation mode, and only the ith excitation electrode E in a certain time periodiIs excited (connected to an excitation source) and canMeasuring the excitation electrode EiAnd all receiving electrodes Rj(j-1, 2, …,10) fluid conductivity information at the intersection; when completing E in sequence1To E10When the electrodes are excited, the fluid conductivity information at all the intersection points on the radial section of the pipeline can be obtained.
The coaxial conductivity sensor is composed of a circular central exciting electrode, an intermediate insulating material and an outer annular receiving electrode, as shown in fig. 2 (b). In order to ensure that the change of the conductive characteristic of the continuous phase is obtained on the premise of no turbulent flow and no influence of taylor bubbles in the pipeline, a liquid extension area is designed in front of the coaxial conductivity sensor, as shown in fig. 2 (c). The extended zone was designed to be angled obliquely upward at an angle of 30 degrees to the radial cross-section of the pipe. The depth of the upper edge of the extension area embedded into the pipeline is 3.6 mm. When the continuous phase (oil-water emulsion) of the oil-gas-water three-phase flow enters the continuation zone, the amplitude of the output signal of the coaxial conductivity sensor can reflect the change of the conductive characteristic of the continuous phase. In order to ensure that the conductivity of the continuous phase at different positions is obtained, the coaxial conductivity sensors are distributed, and as shown in fig. 2(d), three coaxial conductivity sensors are uniformly distributed around the pipeline.
The positions of the conductive grid sensors and the coaxial conductive sensors mounted on the pipeline are shown in fig. 2 (e). For oil-gas-water three-phase flow in a pipeline, the output voltage signal V of the electric conduction grid sensorm,1,Vm,2,…,Vm,10And a marking signal VMark(ii) a Output voltage signal U of distributed coaxial conductivity sensorm,1、Um,2、Um,3And the voltage signals are simultaneously recorded on an upper computer through a data acquisition card.
(2) The conductance grid sensor and distributed coaxial conductance sensor output signals are shown in fig. 3. Marking signal V output by conductive grid sensorMarkIs square wave and is used for indicating the electrode E1,E2,…,E10The order of being excited (ZHai et al,2019, I2MTC, DOI:10.1109/I2 MTC.2019.8827063; ZHai et al,2020, DOI: 10.1109/I2MTC43012.2020.9129032). Marking signal VMarkThe first rising edge of (D) represents E1Is activated and the second rising edge represents E2Is activated and is in a state of being excited,and so on, the circulation is repeated. Marking signal VMarkEvery ten rising edges of (a) correspond to one frame of data, and the number of frames can be represented by k. For the k frame data, the output signal of the conductance grid sensor is Vm,1(k),Vm,2(k),…,Vm,10(k) The output signal of the coaxial conductivity sensor is Um,1(k)，Um,2(k)，Um,3(k)。
(3) For oil-gas-water three-phase flow, the electric conduction grid sensor outputs a signal Vm,1To Vm,10The processing is performed according to the flow shown in FIG. 4. First reading the marking signal VMarkAnd retrieves its rising edge, the ith rising edge indicating that the ith actuation electrode is actuated at that time. Then, for the k frame data, at VMarkCalculating the jth receiving electrode signal V in the time interval between two adjacent rising edgesm,j(k) The extreme difference of (D) is marked as Vm(i,j,k)。
(4) Filling the detection field of the conductive grid sensor with air, and outputting a signal V by the measuring circuitg,1,Vg,2,…,Vg,10. Using the flow shown in FIG. 4 for Vg,1,Vg,2,…,Vg,10By performing the treatment, a very different V can be obtainedg(i, j, k). V under different data framesgThe average of (i, j, k) can be expressed as:
filling the detection field of the conductivity grid sensor with water, and outputting a signal V by the measuring circuitw,1,Vw,2,…,Vw,10. Using the flow shown in FIG. 4 for Vw,1,Vw,2,…,Vw,10By performing the treatment, a very different V can be obtainedw(i, j, k). V under different data frameswThe average of (i, j, k) can be expressed as:
(5) to Vm(i, j, k) is normalized to obtain the final productNormalized signal VN(i,j,k)：
(6) For oil-gas-water three-phase flow, the distributed coaxial conductivity sensor measures the signal Um,1，Um,2，Um,3The process flow of (2) is shown in FIG. 5. First, a mark signal V is readMarkAnd retrieving each rising edge thereof; then, for the k frame data, the average value of the p number coaxial conductance sensor measurement signals is calculated and recorded as Um,p(k)
(7) Filling the coaxial conductive sensor with air in the detection field, and outputting signal U by the measuring circuitg,1，Ug,2，Ug,3(ii) a Signal U is paired according to the flow shown in FIG. 5g,1、Ug,2、Ug,3Processing to obtain the average value of the p-th coaxial conductivity sensor measurement signal, and recording the average value as Ug,p(k) In that respect Calculating U under different data framesg,p(k) Average value of Ug,p。
Filling the coaxial conductivity sensor with water in the detection field, and outputting signal U from the measuring circuitw,1，Uw,2，Uw,3(ii) a Signal U is paired according to the flow shown in FIG. 5w,1、Uw,2、Uw,3Processing to obtain the average value of the p-th coaxial conductivity sensor measurement signal, and recording the average value as Uw,p(k) In that respect Calculating U under different data framesw,p(k) Average value of Uw,p。
(8) Calculating the conductivity correction coefficient delta of continuous phase in oil-gas-water three-phase flowp(k)：
The average of the conductivity correction factors for the three in-line conductivity sensors can be expressed as:
(9) for the normalized signal V in equation (3)N(i, j, k) corrected to give:
(10) according to the correction result of the formula (6), for
And performing bicubic spline interpolation to obtain an imaging result of gas-phase distribution of the oil-gas-water three-phase flow.
The implementation process of the system for oil-gas-water three-phase imaging is described below with reference to the accompanying drawings:
the imaging process of the conductivity grid sensor on the gas phase distribution of the oil-gas-water three-phase flow is shown in fig. 7, and the specific process is as follows:
(1) the conductivity grid sensor and the distributed coaxial conductivity sensor were mounted on a pipe with an internal diameter of 20mm in the relative spatial positions shown in fig. 2. The conductive grid sensor excitation electrodes and the receiving electrodes form a 10 x 10 grid. The diameter of the exciting electrode and the diameter of the receiving electrode are both 0.2 mm. The distance between the radial section of the pipeline where the excitation electrode is located and the radial section of the pipeline where the receiving electrode is located is 2 mm; the distance between two adjacent excitation electrodes is 2mm, and the distance between two adjacent receiving electrodes is 2 mm. The diameter of the central exciting electrode of the coaxial conductivity sensor is 1.5mm, the thickness of the middle insulating material is 0.5mm, and the thickness of the outer annular receiving electrode is 1 mm. The distributed coaxial conductivity sensor was mounted 2030mm from the inlet and the conductive grid sensor was mounted 2230mm from the inlet.
(2) And (5) carrying out a vertical oil-gas-water three-phase flow experiment. Gas phase apparent flow rate U in experimentsgIn the range of 0.055-0.663
m/s, liquid phase (oil phase and water phase) mixed apparent flow rate UslIn the range of 0.037 to 1.179m/s, the oil content f of the liquid phaseoRespectively accounting for 0%, 5%, 10% and 15%, and the specific experimental conditions are shown in Table 1. In the experimental process, under the oil content of a certain liquid phase, the fixed gas phase apparent flow velocity is adopted and gradually changedAnd (3) increasing the apparent flow rate of liquid phase mixing. A total of four runs were performed, each run containing 64 sets of operating conditions. Recording output voltage signal V of conductance grid sensor by data acquisition cardm,1,Vm,2,…,Vm,10And a marking signal VMark(ii) a Simultaneously, recording output voltage signal U of distributed coaxial conductivity sensorm,1，Um,2，Um,3。
TABLE 1 vertical oil-gas-water three-phase flow experiment working condition table (unit m/s)
(3) And (5) carrying out calibration experiments on the conductivity grid sensor and the distributed coaxial conductivity sensor. In the experiment, the pipeline is filled with air, and the output voltage signal V of the electric conduction grid sensor is recorded by using a data acquisition cardg,1,Vg,2,…,Vg,10Simultaneously recording output voltage signal U of distributed coaxial conductivity sensorg,1、Ug,2、Ug,3. Then, the pipeline is filled with full water, and the output voltage signal V of the conductivity grid sensor is recorded by using a data acquisition cardw,1,Vw,2,…,Vw,10Simultaneously recording output voltage signal U of distributed coaxial conductivity sensorw,1、Uw,2、Uw,3。
(4) The data of the conductivity grid sensor collected in the oil-gas-water three-phase flow experiment and calibration experiment are processed according to the flow shown in FIG. 4 to obtain a signal Vm(i,j,k)，Vg(i, j) and Vw(i, j); then, the data of the distributed coaxial conductivity sensor collected in the oil-gas-water three-phase flow experiment and the calibration experiment are processed according to the flow shown in fig. 5 to obtain a signal Um,p(k)，Ug,pAnd Uw,p。
(5) For signal V according to equation (3)m(i, j, k) normalizing to obtain a normalized signal VN(i, j, k); push button
Equation (4) and equation (5) for Um,p(k) Normalization and averaging are performed, and the conductivity correction coefficient δ (k) is output.
(6) The normalized signal V is corrected by the conductivity correction factor delta (k) according to equation (6)N(i, j, k) to obtain a correction signal
(7) To pair
And performing bicubic spline interpolation to obtain an imaging result of gas-phase distribution of the oil-gas-water three-phase flow.
Experimental verification and results:
FIG. 8 shows the oil content f when the liquid phase is usedoAnd when the flow rate is 0.05 and 0.15, the conductance grid sensor is used for three-dimensional imaging of the gas phase distribution in the oil-gas-water three-phase flow. Fig. 8(a) is directly derived from the conductance grid sensor measurement data, without correction for continuous phase conductivity properties, resulting in a longer length of continuous gas phase structure observed at the liquid slug (0.93-0.95s) and large bubble tail (0.99-1s), which is not consistent with the actual flow structure. In fig. 8(b), it can be observed that after the continuous phase conductive characteristic is corrected, the longer continuous gas phase structure disappears, the gas plug and the liquid plug structure in the pipeline can be clearly observed, and the imaging effect is greatly improved. The advantage of the conductive grid sensor with compensation of the conductivity properties for imaging three phase flow can also be seen by comparing fig. 8(c) and 8 (d).
Claims (1)
1. A three-phase flow imaging method of a conductive grid sensor with conductive characteristic compensation is characterized in that a measuring pipeline is a vertically upward pipeline, three-phase flows are oil-gas-water three-phase flows, one of the adopted sensors is the conductive grid sensor, and the other sensor is a distributed coaxial conductive sensor; the conductivity grid sensor comprises excitation electrodes and receiving electrodes, wherein the excitation electrodes are parallel to each other and are positioned on the same radial section of the measuring pipeline, the receiving electrodes are parallel to each other and are positioned on the other radial section of the measuring pipeline, the conductivity grid sensor adopts a cyclic excitation mode, and after one-time cyclic excitation is finished, the conductivity grid sensor outputs one frame of data corresponding to one image of gas phase distribution in three-phase flow of oil, gas and water,
the distributed coaxial conductivity sensor is used for dynamically monitoring the change of continuous phase conductivity characteristics and realizing the real-time correction of the imaging result of the conductivity grid sensor, and comprises three coaxial conductivity sensors; the three coaxial conductivity sensors are uniformly arranged around the same radial section of the measuring pipeline, and the front end of each coaxial conductivity sensor is provided with a liquid continuation area which is designed to be obliquely upward and form an included angle of 30 degrees with the radial section of the measuring pipeline; the method for imaging the oil-gas-water three-phase flow by using the conductive grid sensor and the coaxial conductive sensor comprises the following steps:
1) aiming at oil-gas-water three-phase flow, obtaining output signal V of electric conduction grid sensorm,1,Vm,2,…,Vm,10And a marking signal VMarkFor the k frame data, at VMarkCalculating the jth receiving electrode signal V in the time interval between two adjacent rising edgesm,j(k) The extreme difference of (D) is marked as Vm(i, j, k), wherein i is the excitation electrode number;
2) filling air into the measuring pipeline, and measuring output signal V of the electric conductance grid sensorg,1,Vg,2,…,Vg,10To V pairg,1,Vg,2,…,Vg,10Processing to obtain the range Vg(i, j, k); calculating air phase range V under different data framesgAverage value V of (i, j, k)g(i,j)；
3) Filling the measuring pipeline with water phase, and measuring output signal V of the electric conductance grid sensorw,1,Vw,2,…,Vw,10(ii) a To Vw,1,Vw,2,…,Vw,10Processing to obtain range difference signal Vw(i, j, k); calculating the phase range V of different data frameswAverage value V of (i, j, k)w(i,j)；
4) From the results in steps 1), 2) and 3), on signal Vm(i, j, k) carrying out normalization processing to obtain normalized signal
1,2, ·, 10; k is 1,2, N, where N is the number of frames; 5) obtaining a measurement signal U of a distributed coaxial conductivity sensor aiming at oil-gas-water three-phase flowm,1，Um,2，Um,3For the k frame data, the average value U of the p, p is 1,2,3, coaxial conductivity sensor measurement signals is calculatedm,p(k)；
6) Filling air into the measuring pipeline to obtain a measuring signal U of the distributed coaxial conductivity sensorg,1，Ug,2，Ug,3(ii) a Calculating the average value U of the measurement signal of the No. p coaxial conductivity sensorg,p(k) (ii) a Then, calculating U under different data framesg,p(k) Average value of Ug,p；
7) Filling the measuring pipeline with water phase to obtain a measuring signal U of the distributed coaxial conductivity sensorw,1，Uw,2，Uw,3(ii) a Calculating the average value U of the measurement signal of the No. p coaxial conductivity sensorw,p(k) Then calculating U under different data framesw,p(k) Average value of Uw,p；
8) For the normalized signal V obtained in step 4)N(i, j, k) correcting: calculating the conductivity correction coefficient of a single coaxial conductivity sensor to the continuous phase in the oil-gas-water three-phase flow
Calculating an average value delta (k) of the three conductivity correction coefficients; obtaining a normalized signal VN(i, j, k) correction results
9) According to the correction result of step 8), for
And carrying out bicubic spline interpolation operation to obtain an imaging result of gas-phase distribution of the oil-gas-water three-phase flow.
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