CN108397188B - Sensor for Conductivity Measurement of Aqueous Phase Multiphase Flow in Vertical Riser - Google Patents
Sensor for Conductivity Measurement of Aqueous Phase Multiphase Flow in Vertical Riser Download PDFInfo
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- CN108397188B CN108397188B CN201810126912.1A CN201810126912A CN108397188B CN 108397188 B CN108397188 B CN 108397188B CN 201810126912 A CN201810126912 A CN 201810126912A CN 108397188 B CN108397188 B CN 108397188B
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- 239000008346 aqueous phase Substances 0.000 title claims abstract description 11
- 238000005259 measurement Methods 0.000 title claims description 47
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 176
- 239000012530 fluid Substances 0.000 claims abstract description 11
- 239000012071 phase Substances 0.000 claims description 98
- 230000035945 sensitivity Effects 0.000 claims description 11
- 238000001514 detection method Methods 0.000 claims description 3
- 238000011144 upstream manufacturing Methods 0.000 claims description 3
- 230000000630 rising effect Effects 0.000 abstract 1
- 235000019198 oils Nutrition 0.000 description 25
- 238000000034 method Methods 0.000 description 24
- 239000007791 liquid phase Substances 0.000 description 14
- 230000005514 two-phase flow Effects 0.000 description 13
- 239000007788 liquid Substances 0.000 description 12
- 238000006243 chemical reaction Methods 0.000 description 6
- 230000005284 excitation Effects 0.000 description 6
- 239000003129 oil well Substances 0.000 description 5
- 239000000243 solution Substances 0.000 description 4
- 238000010586 diagram Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 235000019476 oil-water mixture Nutrition 0.000 description 3
- 238000005457 optimization Methods 0.000 description 3
- 239000007864 aqueous solution Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000005316 response function Methods 0.000 description 2
- 229910001220 stainless steel Inorganic materials 0.000 description 2
- 239000010935 stainless steel Substances 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 230000002902 bimodal effect Effects 0.000 description 1
- 230000003750 conditioning effect Effects 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000010291 electrical method Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 230000005251 gamma ray Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000002332 oil field water Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000005855 radiation Effects 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 238000012795 verification Methods 0.000 description 1
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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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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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
- E21B47/00—Survey of boreholes or wells
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
- G01R27/00—Arrangements for measuring resistance, reactance, impedance, or electric characteristics derived therefrom
- G01R27/02—Measuring real or complex resistance, reactance, impedance, or other two-pole characteristics derived therefrom, e.g. time constant
- G01R27/22—Measuring resistance of fluids
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Abstract
本发明涉及一种用于垂直上升管中含水相多相流水相电导率测量的传感器，包括绝缘导流件、测量电极和位于绝缘导流件上方的上端导流件，其中，上端导流件底部迎水面的尺寸大于绝缘导流件顶部背水面的尺寸且其水平投影覆盖绝缘导流件顶部背水面的水平投影；在绝缘导流件的背水面和位于其上方的上端导流件的迎水面之间形成的腔体称之为全水获取区，全水获取区的高度应当保证自下而上新流入的流体能够在其内分离并与存留的流体之间产生交换。上端导流件的主体为柱状，其底部开设有环形凹槽；测量电极固定在绝缘导流件的顶部。
The invention relates to a sensor for measuring the electrical conductivity of aqueous phase multiphase flow in a vertical rising pipe, comprising an insulating flow guide, a measuring electrode and an upper flow guide located above the insulating flow guide, wherein the upper flow guide The size of the bottom water-facing surface is larger than the size of the top backwater surface of the insulating deflector and its horizontal projection covers the horizontal projection of the top backwater surface of the insulating deflector; The cavity formed between the water surfaces is called the total water acquisition area, and the height of the total water acquisition area should ensure that the newly inflowing fluid from bottom to top can be separated and exchanged with the remaining fluid. The main body of the upper air guide is cylindrical, and the bottom is provided with an annular groove; the measuring electrode is fixed on the top of the insulating guide.
Description
Technical Field
The invention relates to a sensor for measuring the water phase conductivity of a water-phase multiphase flow, which can be used for electrically measuring the split-phase volume concentration of oil water/gas water/oil gas water/multiphase flow in a production well of an oil field developed by water injection.
Background
Along with different exploitation modes in the oilfield water injection development process, oil-water/gas-water/oil-gas-water/multiphase flow exploitation mixed liquid often appears in an oil well. In order to understand the production dynamic characteristics of the oil well and optimize reservoir management, the water holdup parameters of the oil well need to be dynamically monitored in real time. At present, the conductivity method or the capacitance method is a conventional measurement means for obtaining the water retention rate, and because of the geological structure difference of oil and gas fields in different regions and the change of the property of formation water from time to time in the water injection development process of the oil field, the conductivity and the dielectric constant of a water phase in an oil well produced liquid are changed in a complex way, which brings great influence to the water retention rate measurement result mainly based on the electrical method (conductivity or capacitance). Therefore, in order to reduce the influence of the change of the conductivity of the water phase on the measurement result of the water holdup, the real-time monitoring of the change of the conductivity of the water phase in the oil well has important practical significance for improving the measurement precision of the water holdup.
Microwave technology (United States Patent, Patent No.: US6831470B2, Date of Patent: Dec.14,2004) and bimodal gamma-ray method (saline independent measurement of gas volume fraction in oil/gas/water slice, Applied Radiation and Isotopes,2000,53: 595-.
Disclosure of Invention
The invention provides a water phase conductivity measuring device for multiphase flow of water-containing phase in a vertical riser, which has the characteristics of simple structure, higher precision and capability of realizing real-time dynamic measurement of the water phase conductivity. The technical scheme is as follows:
a sensor for measuring the water phase conductivity of a multiphase flow of an aqueous phase in a vertical riser comprises an insulating flow guide part, a measuring electrode and an upper end flow guide part positioned above the insulating flow guide part, wherein the size of the upstream surface of the bottom of the upper end flow guide part is larger than that of the back surface of the top of the insulating flow guide part, and the horizontal projection of the upper end flow guide part covers that of the back surface of the top of the insulating flow guide part; the cavity formed between the back surface of the insulating flow guide part and the upstream surface of the upper end flow guide part above the insulating flow guide part is called as a full water acquisition area, and the height of the full water acquisition area is required to ensure that the fluid which flows in from bottom to top can be separated in the full water acquisition area and exchanged with the reserved fluid. The main body of the upper end flow guide piece is columnar, and the bottom of the upper end flow guide piece is provided with an annular groove; the measuring electrode is fixed on the top of the insulating flow guide piece.
Preferably, the annular groove is shaped in two semi-circles in an axial sectional view. The measuring electrode comprises a circular electrode and a ring electrode positioned on the periphery of the circular electrode. The main body of the insulating flow guide part is columnar, and the incident flow position of the insulating flow guide part is a hemisphere. By optimizing the size of the measuring electrode, the measuring electrode has higher water phase conductivity measuring sensitivity and linearity.
Due to the adoption of the technical scheme, the invention has the following measurement advantages:
(1) the insulating flow guide part and the total water acquisition area can dynamically acquire the total water measurement environment in the oil-water/gas-water/oil-gas-water/multiphase flow process.
(2) The sensor for measuring the water phase conductivity can realize the direct measurement of the water phase conductivity based on a conductivity method through size optimization and a specially designed measuring circuit, and has the advantages of high precision, high response speed, stable performance, wide applicable multiphase flow pattern range and the like.
(3) The sensor is suitable for the oil-water/gas-water/oil-gas-water/multi-phase flow state in the vertical riser, and the output response of the measurement of the water phase conductivity of the sensor is not influenced by the flow parameters such as the multi-phase flow pattern, the split-phase volume concentration, the split-phase apparent flow rate and the like.
Drawings
Fig. 1 is an overall structural view of an aqueous phase conductivity measurement sensor.
Fig. 2 is a detailed structural diagram of the water-phase conductivity measuring sensor total water acquisition area and the measuring electrode.
Fig. 3 is a structure view of the upper end flow guide of the whole water acquisition area, wherein (a) is a top view of the upper end flow guide, and (b) is an arbitrary axial sectional view.
Fig. 4 is a block diagram of the entire aqueous phase conductivity measurement sensing system.
FIG. 5 is a graph showing the response output of a dynamic measurement device for aqueous phase conductivity using the sensor of the present invention for aqueous solutions of different conductivities.
In FIG. 6, (a), (b), and (c) are the total water measurement response outputs of the dynamic measurement device for aqueous phase conductivity at 1000. mu.s/cm, 4000. mu.s/cm, and 8000. mu.s/cm for gas-liquid two-phase bubble flow (bubble flow), slug flow (slug flow), and mixed flow (churn flow), respectively. In the figure, UsgAnd UswThe gas and water phase apparent flow rates are respectively.
FIG. 7 (a), (b) and (c) are dynamic response output values of the aqueous phase conductivity measuring device when the aqueous phase conductivity is changed from 8000. mu.s/cm to 1000. mu.s/cm in the gas-liquid two-phase flow of different flow patterns. In the figure, UsgAnd UswThe gas and water phase apparent flow rates are respectively.
In FIG. 8, (a), (b) and (c) show the water phase conductivity dynamic measuring device at different oil-water mixture flow rates U when the water phase conductivity is 1000 μ s/cm during the oil-water two-phase flowmAnd water content KwThe full water measurement output value at time.
FIG. 9 (a), (b) and (c) are graphs showing the water phase conductivity at different flow rates U of the oil-water mixture, when the water phase conductivity is 4000. mu.s/cmmAnd water content KwThe full water measurement output value at time.
FIG. 10 (a), (b) and (c) are graphs showing the water phase conductivity dynamic measuring device at different oil-water mixture flow rates U when the water phase conductivity is 8000. mu.s/cmmAnd water content KwThe full water measurement output value at time.
FIG. 11 (a), (b) and (c) are at a lower flow rate UmWhen the conductivity of the water phase is changed from 8000 mu s/cm to 1000 mu s/cm in the oil-water two-phase flow process, the dynamic measuring device for the conductivity of the water phase is arranged at different water contents KwThe dynamic response of time to output value.
FIG. 12 (a), (b) and (c) are at a higher flow rate UmIn the oil-water two-phase flow process, when the conductivity of the water phase is changed from 8000 mu s/cm to 1000 mu s/cm, the dynamic measuring device for the conductivity of the water phase is arranged at different water contents KwThe dynamic response of time to output value.
In FIG. 13, (a), (b) and (c) show that in the three-phase flow process of oil, gas and water, the dynamic measuring device for the conductivity of the water phase is in bubble flow (bubble flow), slug flow (slug flow), mixed flow (churn flow) and oil content f of different liquid phases when the conductivity of the water phase is 1000 mus/cmoThe full water measurement output value at time.
In FIG. 14, (a), (b) and (c) show that in the three-phase flow process of oil, gas and water, the dynamic measuring device for the conductivity of the water phase is at bubble flow (bubble flow), slug flow (slug flow), mixed flow (churn flow) and the oil content f of different liquid phasesoThe full water measurement output value at time.
FIG. 15 (a), (b) and (c) shows that in the three-phase flow process of oil, gas and water, the dynamic measuring device for the water phase conductivity is at bubble flow (bubble flow), slug flow (slug flow), mixed flow (churn flow) and oil content f of different liquid phases when the water phase conductivity is 8000 μ s/cmoThe full water measurement output value at time. In the figure, UsgAnd UslThe apparent flow rates of the gas phase and the oil-water mixed liquid are respectively.
FIG. 16 (a), (b) and (c) show the bubble flow (bubb) in oil, gas and waterle flow), when the conductivity of the water phase is changed from 8000 mu s/cm to 1000 mu s/cm, the oil content f of the water phase in different liquid phases is dynamically measured by the deviceoThe dynamic response output value of.
FIG. 17 (a) (b) (c) shows the oil content f of the dynamic measuring device of the water phase conductivity in different liquid phases when the water phase conductivity is changed from 8000 mu s/cm to 1000 mu s/cm in the case of oil-gas-water three-phase slug flow (slug flow)oThe dynamic response output value of.
FIG. 18 (a), (b) and (c) shows the oil contents f of different liquid phases of the dynamic measuring device for the conductivity of the water phase when the conductivity of the water phase is changed from 8000 to 1000 μ s/cm in the case of the mixed flow of oil, gas and water (churn flow)oThe dynamic response output value of. In the figure, UsgAnd UslThe apparent flow rates of the gas phase and the oil-water mixed liquid are respectively.
The reference numbers illustrate:
1. a sensor conduit; 2. an insulating flow guide member; 3. a full water acquisition zone; 4. a flow guide member at the upper end of the full water acquisition area; 5. an excitation electrode; 6. a receiving electrode; 7. an excitation source signal; 8. an I/V conversion circuit; 9. an inverting amplifier; 10. and a demodulation module.
Detailed Description
The invention is described in detail below with reference to the figures and examples.
The invention is characterized in that the full water measuring environment in three multiphase flow processes of oil water/gas water/oil gas water is obtained by designing a flow guide part and a full water obtaining area, an optimally designed water phase conductivity measuring electrode is installed in the full water measuring environment, and the conductivity information of the full water is converted into a voltage signal through a signal conditioning circuit and is sent to acquisition and processing equipment.
The following describes the water phase conductivity measuring device of the water phase multiphase flow in the vertical riser of the invention with reference to the attached drawings.
The overall structure diagram of the water conductivity measurement sensor is shown in fig. 1, and the water conductivity measurement sensor comprises a sensor pipeline 1, an insulating diversion piece 2, a tail full water acquisition area 3, an internal conductivity measurement electrode and a full water acquisition area upper end diversion piece 4. The detailed structure of the full water acquisition area and the measuring electrode is shown in fig. 2, and comprises a stainless steel exciting electrode 5 and a stainless steel receiving electrode 6. The detailed structure of the diversion piece at the upper end of the full water acquisition area is shown in figure 3. The centers of the insulating flow guide piece, the full water acquisition area and the upper end flow guide piece are coincided with the center of the pipeline. The inner diameter D of the sensor pipeline is 20mm, the incident flow position of the insulating flow guide piece is a hemisphere, the rear end of the insulating flow guide piece is a cylinder with the outer diameter D1 being 10mm, and the total length H1 of the insulating flow guide piece is 70 mm. The inner diameter D2 of the full water acquisition area is 8mm, the height H2 is higher than the detection height of the electrode, the external fluid can be well separated in the full water acquisition area and exchanged with the internal fluid, and H2 is set to be 20mm according to the working condition of the measured fluid. The upper end guide piece has a three-dimensional structure as shown in fig. 3(a), the incident flow surface of the upper end guide piece is a semicircular annular groove, the rear end of the upper end guide piece is a cylinder with the diameter D3 being 12mm, and the overall height H3 being 50 mm. Any axial section of the semi-circular groove is two tangent flow guiding semicircles, and as shown in fig. 3(b), the radius D4 of each flow guiding semicircle is 3 mm. The height H4 of the outer edge of the full water acquisition area from the front end of the upper end flow guide piece can be adjusted according to the flowing working condition so as to ensure that the fluid returns to the full water acquisition area after contacting the upper end flow guide piece, and the internal fluid is well separated and exchanged. H4 is set to be 2mm for the measured gas-liquid and oil-water two-phase flow, and H4 is set to be 8mm for the measured oil-gas-water three-phase flow. The conductivity measuring electrode adopts the structural form shown in fig. 2, the radius of the circular central exciting electrode is r, the width of the outer ring type receiving electrode is d, and the distance between the outer diameter of the exciting electrode and the inner diameter of the receiving electrode is l.
The invention adopts a finite element method to optimize the structural size of the electrode, and the parameters to be optimized comprise the radius r of a circular central excitation electrode, the width d of an outer ring type receiving electrode and the distance l between the outer diameter of the excitation electrode and the inner diameter of the receiving electrode. In finite element simulation software ANSYS, the relative resistivity of water is set as rhow1000 Ω m, gas relative resistivity ρg＝1×1020Ω m, electrode resistivity ρs＝1.72×10-8Omega m. Selecting SOLID231 as a unit type, and subdividing the model by adopting a free subdivision method. A constant current of 0.1mA is applied to the excitation electrode 5, a constant current of-0.1 mA and a boundary voltage of 0V is applied to the reception electrode 6. A non-conductive ball is placed on the measuring section in the model to simulate the movement of the non-conductive phase. SmallWhen the ball is at different positions, the voltage of the exciting electrode changes, so that the sensitivity of the conductivity sensor can be reflected by the changed voltage of the exciting electrode.
The invention adopts the detection of field uniformity error parameters (SVP) and the average relative sensitivity (S) of the sensoravg) As an optimization objective. The sensor sensitivity is defined as:
wherein, Δ U ═ U0-U，[ΔU(x,y,z)]maxIs the maximum value of the voltage change after traversing the coordinates (x, y, z), U0The voltage output value is the voltage output value when the water is full, and U is the output voltage of the sensor when the insulating small balls exist.
Average relative sensitivity (S)avg) The meaning of (1) is the average of all positional sensitivities of the cross-section, defined as:
the uniformity error parameter (SVP) defining the measurement cross-section is:
in the formula, SdevThe standard deviation of the relative sensitivity of different positions on the measurement cross section is defined as:
obviously, SavgThe larger the value, the higher the sensor sensitivity, the smaller the SVP value, i.e., the smaller the uniformity error.
And (3) carrying out optimization design by adopting a single-factor alternation method, namely only one factor is changed, the rest factors are fixed, and then carrying out gradual collocation experiment comparison to obtain an optimal collocation scheme. And finally determining through simulation comparison: the radius r of the exciting electrode is 0.75mm, the electrode spacing l is 0.5mm, and the width d of the receiving electrode is 1 mm. The relative sensitivity of the sensor is highest and the uniformity error is smallest.
The measuring and sensing system of the invention is shown in figure 4, a signal source adopts a sinusoidal voltage alternating current signal with 20kHz and a peak value of 4V, and the equivalent resistance between two electrodes is assumed to be RmThe effective value of the excitation signal is VsThen the response function of the system is:
wherein, V0To measure the reference output value of the system, again because:
Rm＝1/G
G＝σA2/l2
g is the conductance between the electrodes, σ is the solution conductivity, A2Is the area opposite to the polar plate, |2For the plate spacing, the response function of the system can be written as:
when the electrodes and the circuit are determined,
V0the change amount of the output voltage is a constant, so that the change amount of the output voltage is in a proportional relation with the change amount of the solution conductivity sigma (mu s/cm) in theory, and therefore, the system has high sensitivity and linearity to the conductivity of the solution. Fig. 5 shows the output values and the corresponding relationship of the dynamic measuring device for the conductivity of the water phase of the present invention under different conductivity aqueous solutions, and it can be seen that the system output value and the conductivity of the water are in a linear relationship, which is consistent with the above theoretical derivation, and in the actual measurement, as long as the output of the water conductivity measuring sensor is obtained, the conductivity information of the solution can be obtained according to the corresponding relationship of fig. 5.
Experimental verification and results:
FIG. 6 is a graph showing the measured output values of the dynamic measuring apparatus for the water phase conductivity under the conditions of bubble flow, slug flow, mixed flow and full water when the water phase conductivity is 1000. mu.s/cm, 4000. mu.s/cm and 8000. mu.s/cm in the gas-liquid two-phase flow. It can be seen that under different conductivities and flow patterns, the output of the water conductivity dynamic measuring device is stable and is close to the output of single-phase full water, and the water phase conductivity information in the gas-liquid two-phase flow process can be obtained according to the corresponding relation of the figure 5. Defining the relative error E ═ σ of the conductivity measurementm-σ)/σ]X 100, where σmIn order to measure the conductivity of the obtained water, sigma is the actual water phase conductivity, and the device has higher precision for measuring the water phase conductivity in the gas-liquid two-phase flow.
FIG. 7 is the dynamic response of the water phase conductivity measuring device when the water phase conductivity changes from 8000 μ s/cm to 1000 μ s/cm in the gas-liquid two-phase flow process of different flow patterns. It can be seen that the measuring device has good dynamic tracking capability for the three flow-type water phase conductivity measuring devices, the water phase conductivity conversion time is short for slug flow (slug flow) with the lowest mixed flow rate, and the water phase conductivity measuring performance is better for bubble flow (bubble flow) and mixed flow (churn flow) with higher flow rates. In conclusion, the measuring device can dynamically obtain the water phase conductivity information in the gas-liquid two-phase flow process, the measurement response output is not influenced by the flow type change, the measurement precision is high, and the measurement range is wide.
FIGS. 8 to 10 show that the dynamic measuring device for the conductivity of the water phase is at different liquid phase mixing flow rates U when the conductivity of the water is 1000 mus/cm, 4000 mus/cm and 8000 mus/cm respectively during the oil-water two-phase flow processmWater content KwAnd the measured response output value at full water. It can be seen that the measurement response output of the dynamic measurement device for the water phase conductivity is stable when the conductivity, the liquid phase mixed flow rate and the water content are different, and is close to the output when the water is full in a single phase, the water phase conductivity information in the oil-water two-phase flow process can be obtained according to the corresponding relation of the figure 5, and the relative error index shows that the device has higher performanceThe measurement accuracy of the conductivity of the water phase in the oil-water two-phase flow is improved.
FIGS. 11-12 show the dynamic response output of the measuring device at lower and higher mixing flow rates when the conductivity of the aqueous phase was changed from 8000 to 1000. mu.s/cm. It can be seen that the measuring device has better dynamic tracking capability for measuring the water phase conductivity, and in addition, the dynamic conversion time of the water phase conductivity is longer for the flowing working conditions with lower mixing flow rate and lower water content, and the dynamic conversion performance of the water phase conductivity is better for the flowing working conditions with higher mixing flow rate and higher water content. In conclusion, the device can better obtain the water phase conductivity information in the oil-water two-phase flow process, the measurement output response is not influenced by the flow velocity and the water content change, the measurement precision is high, and the measurement range is wider.
FIGS. 13 to 15 show that when the water phase conductivity is 1000 mus/cm, 4000 mus/cm and 8000 mus/cm, respectively, the water phase conductivity measuring device is in three flow patterns (bubble flow, slug flow and mixed flow) and different liquid phase oil content foAnd the measured response output value at full water. It can be seen that under different conductivities, flow patterns and liquid-phase oil contents, the measurement response output of the dynamic measurement device for the water-phase conductivity is stable, is not influenced by the flow patterns and the oil contents, and is close to the output value of single-phase full water. And obtaining the water phase conductivity information in the oil-gas-water three-phase flow process according to the corresponding relation of the figure 5. It can be seen that the device has higher water phase conductivity measurement precision in the oil-gas-water three-phase flow.
FIGS. 16 to 18 show the dynamic response output values of the measuring device when the conductivity of the water phase is changed from 8000 mu s/cm to 1000 mu s/cm under different flow patterns of oil-gas-water three-phase flow and liquid-phase oil-containing rate flow conditions. It can be seen that the measuring device has better dynamic tracking capability of the water phase conductivity for three flow patterns. For slug flow with lower mixing flow rate and higher liquid phase oil content, the dynamic conversion time of the water phase conductivity is longer, the dynamic conversion time of the water phase conductivity can be reduced by reducing the oil content of the liquid phase and increasing the mixing flow rate, and therefore, the dynamic tracking performance of the water phase conductivity is better for bubble flow and mixed flow with higher mixing flow rate. In conclusion, the device can dynamically obtain the water phase conductivity information in the oil-gas-water three-phase flow process, the measurement response output is not influenced by the flow pattern and the liquid phase oil content change, the measurement precision is high, and the measurement range is wide.
Claims (2)
1. A sensor for measuring the water phase conductivity of a multiphase flow of an aqueous phase in a vertical riser comprises an insulating flow guide part, a measuring electrode and an upper end flow guide part positioned above the insulating flow guide part, wherein the diameter of a water-facing surface at the bottom of the upper end flow guide part is larger than that of a back water surface at the top of the insulating flow guide part, and the horizontal projection of the upper end flow guide part covers the horizontal projection of the back water surface at the top of the insulating flow guide part; a cavity formed between the back water surface of the insulating flow guide part and the upstream surface of the upper end flow guide part above the insulating flow guide part is called as a full water acquisition area, and the height of the full water acquisition area is required to ensure that the fluid which flows in from bottom to top can be separated in the full water acquisition area and exchanged with the reserved fluid; the main body of the upper end flow guide piece is columnar, and the bottom of the upper end flow guide piece is provided with an annular groove; the measuring electrode is fixed on the top of the insulating flow guide piece; the measuring electrode comprises a circular electrode and an annular electrode positioned on the periphery of the circular electrode; the main body of the insulating diversion part is columnar, the incident flow position of the insulating diversion part is a hemisphere, the centers of a full water acquisition area and the diversion part at the upper end of the insulating diversion part are superposed with the center of the pipeline, and the height of the full water acquisition area is higher than the detection height of the electrode; in an axial sectional view, the annular groove is shaped in two semicircles.
2. The sensor of claim 1, wherein the measurement electrode has high water phase conductivity measurement sensitivity and linearity by optimizing the measurement electrode size.
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| CN101967969A (en) * | 2010-10-22 | 2011-02-09 | 大庆油田有限责任公司 | High-resolution water cut meter based on distributary method |
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| GB2466405B (en) * | 2007-10-12 | 2013-05-01 | Schlumberger Holdings | Measure of quantities of oil and water in multiphase flows |
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| CN101967969A (en) * | 2010-10-22 | 2011-02-09 | 大庆油田有限责任公司 | High-resolution water cut meter based on distributary method |
| CN203374266U (en) * | 2013-05-28 | 2014-01-01 | 燕山大学 | Longitudinal multi-pole full-hole specific retention measurement conductivity sensor |
| EP3190400A1 (en) * | 2016-01-08 | 2017-07-12 | Openfield | A downhole fluid properties analysis probe, tool and method |
| CN206681723U (en) * | 2017-04-28 | 2017-11-28 | 王昊 | A kind of microwave specific retention combination logging instrument for output section |
| CN107402238A (en) * | 2017-06-19 | 2017-11-28 | 天津大学 | Oil well oil-water two phase flow measurement of water ratio method under the effect of binary chemical liquids |
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