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Journal articles on the topic 'Oil flow measurement'

Author: Grafiati

Published: 4 June 2021

Last updated: 1 February 2022

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1

Bonilla Riaño, Adriana, Antonio Carlos Bannwart, and Oscar M. H. Rodriguez. "Film thickness planar sensor in oil-water flow: prospective study." Sensor Review 35, no. 2 (March 16, 2015): 200–209. http://dx.doi.org/10.1108/sr-09-2014-702.

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Purpose – The purpose of this paper is to study a multiphase-flow instrumentation for film thickness measurement, especially impedance-based, not only for gas–liquid flow but also for mixtures of immiscible and more viscous substances such as oil and water. Conductance and capacitive planar sensors were compared to select the most suitable option for oil – water dispersed flow. Design/methodology/approach – A study of techniques for measurement of film thickness in oil – water pipe flow is presented. In the first part, some measurement techniques used for the investigation of multiphase flows are described, with their advantages and disadvantages. Next, examinations of conductive and capacitive techniques with planar sensors are presented. Findings – Film thickness measurement techniques for oil–water flow are scanty in the literature. Some techniques have been used in studies of annular flow (gas–liquid and liquid–liquid flows), but applications in other flow patterns were not encountered. The methods based on conductive or capacitive measurements and planar sensor are promising solutions for measuring time-averaged film thicknesses in oil–water flows. A capacitive system may be more appropriate for oil–water flows. Originality/value – This paper provides a review of film thickness measurements in pipes. There are many reviews on gas – liquid flow measurement but not many about liquid – liquid flow.

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2

Shiomi, Tomoyasu, and Yuji Yagura. "Fuel Oil Flow Measurement on Ship." Marine Engineering 52, no. 3 (2017): 342–46. http://dx.doi.org/10.5988/jime.52.342.

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3

Li, Yingwei, Jing Gao, Xingbin Liu, and Ronghua Xie. "Energy Demodulation Algorithm for Flow Velocity Measurement of Oil-Gas-Water Three-Phase Flow." Mathematical Problems in Engineering 2014 (2014): 1–13. http://dx.doi.org/10.1155/2014/705323.

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Flow velocity measurement was an important research of oil-gas-water three-phase flow parameter measurements. In order to satisfy the increasing demands for flow detection technology, the paper presented a gas-liquid phase flow velocity measurement method which was based on energy demodulation algorithm combing with time delay estimation technology. First, a gas-liquid phase separation method of oil-gas-water three-phase flow based on energy demodulation algorithm and blind signal separation technology was proposed. The separation of oil-gas-water three-phase signals which were sampled by conductance sensor performed well, so the gas-phase signal and the liquid-phase signal were obtained. Second, we used the time delay estimation technology to get the delay time of gas-phase signals and liquid-phase signals, respectively, and the gas-phase velocity and the liquid-phase velocity were derived. At last, the experiment was performed at oil-gas-water three-phase flow loop, and the results indicated that the measurement errors met the need of velocity measurement. So it provided a feasible method for gas-liquid phase velocity measurement of the oil-gas-water three-phase flow.

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4

Xue, Long, Li Jun Sun, and Su Na Guo. "Intelligent Turbine Flowmeter for Viscous Oil Flow Measurement." Advanced Materials Research 694-697 (May 2013): 1074–77. http://dx.doi.org/10.4028/www.scientific.net/amr.694-697.1074.

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Turbine flowmeter is significant, but the change of viscosity has a remarkable impact on the accuracy of the turbine flowmeter. Aiming at this problem, the experiment was carried out on the viscosity variable oil flow facility. New software compensation method for viscosity was put forward with the developed intelligent turbine secondary instrument. Firstly the viscosity was compensated, viscosity was regarded as independent variable, average meter factor was regarded as dependent variable, the polynomial was fitted; then the flow rate was compensated, flow rate was regarded as independent variable, the average offset between meter factor got by viscosity compensation and experiment was regarded as dependent variable. The polynomial was fitted, the sum of results of two functions was regarded as the final meter factor. The test demonstrated: with the software compensation the accuracy of intelligent turbine flowmeter changed from 8.0% to better than 2.3%.

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5

WANG, Weiwei. "Voidage Measurement of Gas-Oil Two-phase Flow." Chinese Journal of Chemical Engineering 15, no. 3 (June 2007): 339–44. http://dx.doi.org/10.1016/s1004-9541(07)60090-1.

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6

Jin, Zhou, Liang, Wang, Zhai, and Wei. "Flow Measurement of Oil-Water Two-Phase Flow at Low Flow Rate Using the Plug-in Conductance Sensor Array." Sensors 19, no. 21 (October 25, 2019): 4649. http://dx.doi.org/10.3390/s19214649.

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In order to improve the flow measurement accuracy of oil-water two-phase flow at low flow rate, this paper presents a plug-in conductance sensor array (PICSA) for the measurement of water holdup and cross-correlation velocity. Due to the existence of the insert body in PICSA, the effect of slippage and the non-uniform distribution of dispersed phase on the measurement of oil-water two-phase flow at low flow rate can be reduced. The finite element method is used to analyze the electric field distribution characteristics of the plug-in conductance sensor, and the sensor geometry is optimized. The dynamic experiment of oil-water two-phase flow is carried out where water cut Kw and mixture velocity Um are set in the range of 10–98% and 0.0184–0.2580 m/s respectively. Experimental results show that the PICSA has good resolution in water holdup measurement for dispersed oil-in-water slug flow (D OS/W), transition flow (TF), dispersed oil-in-water bubble flow (D O/W) and very fine dispersed oil-in-water bubble flow (VFD O/W). In addition, the cross-correlation velocity of the oil-water two-phase flow is obtained by using the plug-in upstream and downstream conductance sensor arrays. The relationship between the cross-correlation velocity and mixture velocity is found to be sensitive to the change of flow pattern, but it has a good linear relationship under the same flow pattern. Based on the flow pattern identification, a good prediction result of the mixture velocity is obtained using kinematic wave theory. Finally, a high precision prediction of the individual phase volume fraction of oil-water two-phase flow at low flow rate is achieved by using the drift flux model.

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7

Wang, H., D. Vedapuri, J. Y. Cai, T. Hong, and W. P. Jepson. "Mass Transfer Coefficient Measurement in Water/Oil/Gas Multiphase Flow." Journal of Energy Resources Technology 123, no. 2 (November 10, 2000): 144–49. http://dx.doi.org/10.1115/1.1368121.

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Mass transfer studies in oil-containing multiphase flow provide fundamental knowledge towards the understanding of hydrodynamics and the subsequent effect on corrosion in pipelines. Mass transfer coefficient measurements in two-phase (oil/ferri-ferrocyanide) and three-phase (oil/ferri-ferrocyanide/nitrogen) flow using limiting current density technique were made in 10-cm-dia pipe at 25 and 75 percent oil percentage. Mass transfer coefficients in full pipe oil/water flow and slug flow were studied. A relationship is developed between the average mass transfer coefficient in full pipe flow and slug flow. The mass transfer coefficient decreased with a decrease of in-situ water cut. This was due to the existence of oil phase, which decreased the ionic mass transfer diffusion coefficient.

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8

Isayev, M. M., M. B. Mammadova, N. M. Khasayeva, F. Sh Aghayeva, and N. Kh Badalova. "Study oil density in flow, system of automated measurement and inaccuracies." Azerbaijan Oil Industry, no. 12 (December 15, 2020): 39–44. http://dx.doi.org/10.37474/0365-8554/2020-12-39-44.

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The paper reviews the issues of specification of fluid fuel amount with high measuring accuracy transported through oil pipelines. The operation algorithm of vibration-frequency densitometer for automatic measurement of fluid fuel density with high measuring accuracy in technological process in the exploitation conditions is based on the hybrid test method. For this purpose test equations on measuring links using simple additive and multiplicative tests, as well as their combinations have been developed, test equations composed, and as a result of their solution the main test equation obtained. The mathematic-statistic estimation of the results of densitometer measurements correcting test algorithms for the definition of measurement errors and composing inaccuracies, the method of automated calibration are presented as well.

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9

Kinghorn, F. C. "Challenging Areas in Flow Measurement." Measurement and Control 21, no. 8 (October 1988): 229–35. http://dx.doi.org/10.1177/002029408802100801.

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Flow measurement has many applications and a wide range of techniques is used. In many industrial sectors there are particular difficulties in measuring flowrate and often special solutions are required. Some of the problems in the oil and gas, biotechnology, automobile and water supply industries are described and the shortcomings or difficulties associated with the methods currently being used are identified. There are also numerous technical difficulties which span several industrial sectors and the topics of multi-phase flow, direct mass flow measurement, pipework configuration effects and computational fluid dynamics are covered, although it is recognised that these are only a few of a very much larger number of difficult areas.

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10

Xu, Jiu, and Pega Hrnjak. "Flow Visualization and Experimental Measurement of Compressor Oil Separator." SAE International Journal of Passenger Cars - Mechanical Systems 11, no. 5 (April 3, 2018): 377–88. http://dx.doi.org/10.4271/2018-01-0067.

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11

Li, Yi, Wuqiang Yang, Cheng-gang Xie, Songming Huang, Zhipeng Wu, Dimitrios Tsamakis, and Chris Lenn. "Gas/oil/water flow measurement by electrical capacitance tomography." Measurement Science and Technology 24, no. 7 (June 12, 2013): 074001. http://dx.doi.org/10.1088/0957-0233/24/7/074001.

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12

Wang, D. Y., N. D. Jin, Y. S. He, L. S. Zhai, and Y. Y. Ren. "Flow measurement of oil-in-water flows in vertical low flow rate and high water-cut flow conditions." Journal of Physics: Conference Series 1065 (August 2018): 092010. http://dx.doi.org/10.1088/1742-6596/1065/9/092010.

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13

Gao, Qiang, and Hong Ye Zhao. "Design of Flare Gas Flow Measurement System on Offshore Oil Platform." Applied Mechanics and Materials 385-386 (August 2013): 460–63. http://dx.doi.org/10.4028/www.scientific.net/amm.385-386.460.

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Aiming at the problems of flare gas flow monitoring on offshore oil platform, a flare gas flow measurement system is designed. This system is integrated in the whole flare control system and reaches the effective monitoring of flare gas flow. Besides it adopts ultrasonic flow-meters for the more accurate flow-meter data and adopts hot-cap method for the realization of being installed without halting production. Results indicate that the design could offshore oil platform improve the efficiency and safety of production in offshore oil platform.

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14

Morsi, Iman, and Loay Mohy El Din Rasheed. "Microcontroller System for Oil Refinery Parameters Measurements Based on Piezoresistive and Strain Gauge Pressure Sensors." Applied Mechanics and Materials 249-250 (December 2012): 1133–38. http://dx.doi.org/10.4028/www.scientific.net/amm.249-250.1133.

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In oil refinery there is a variety of physical parameters such as pressure, flow rate and level that need to be measured. A microcontroller system is built based on PIC 16F877A, piezoresistive differential pressure DP sensor (24PC series) and strain gauge DP sensor (IDP-10) with ranges from 0 to 15psi. The results of the microcontroller system showed that; the percentage error for piezoresistive sensor in pressure from 0.43808% to 8.613 %, in flow rate from 0.21929% to 20.340%, and in level from 0.43808% to 2.5789%. While the percentage error for strain gauge sensor from 0.846% to 1.946% for pressure measurement, from 0.1% to 0.4% for flow rate measurement and from 0% to 0.64% for level measurement. The percentage error of the piezoresistive sensor is more than the percentage error of the strain gauge sensor: for pressure measurement by about 6.667%, for flow rate measurement by about 19.94% and for level measurement by about 1.9389%. Fuzzy logic is used to predict the output surface of pressure, flow rate, and level measurements.

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15

Kouba, G. E. "A New Look at Measurement Uncertainty of Multiphase Flow Meters." Journal of Energy Resources Technology 120, no. 1 (March 1, 1998): 56–60. http://dx.doi.org/10.1115/1.2795010.

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At present, no standard of presenting multiphase flow meter (MPFM) uncertainties has been accepted by industry. Consequently, vendors’ specifications may only indicate velocity and component fraction uncertainties, while customers will typically need to know the overall uncertainty of the hydrocarbon (gas or oil) flow rate. Moreover, comparisons between different meters, meter locations, and metering strategies are difficult without the combined uncertainties of the hydrocarbon measurement. A simple uncertainty analysis (UA) is presented as a means of combining individual measurement uncertainties to determine an overall uncertainty for one of the mixture components, e.g., oil rate. The results are displayed as contour lines of constant oil rate uncertainty on plots of gas fraction versus water cut. Examples illustrate how the uncertainty of oil rate measurement might be reduced by operating the meter at higher pressure, or employing partial separation strategies, and limitations of such strategies.

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16

Nowakowski, Jacek, Robert Banasiak, Radosław Wajman, and Dominik Sankowski. "MULTI PHASE FLOW MEASUREMENTS WITH THE APPLICATION OF ECT/ERT DECART MULTIMODALITY TOMOGRAPH." Informatics Control Measurement in Economy and Environment Protection 7, no. 1 (March 30, 2017): 46–49. http://dx.doi.org/10.5604/01.3001.0010.4581.

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The multi-phase flow measurements are very important tasks in many areas of industrial processes applications. One of them is undersea exploration of oil in the petroleum industry. The submitted paper presents application of DECART tomograph designed and built in Lodz University of Technology - together with combined measurements of signals acquired from gamma ray measurement system. Use of all measuring modalities allowed for performing measurements of a flow composed of sea water, oil and gas. The paper presents theoretical principles applied to design multimodality tomograph and results of experiments performed in the University of Bergen. Measurement confirmed that multi-modality approach allows giving fast and reliable on-line results of measurements of composition of multi-phase flow. Applied algorithms allowed to speed up on-line measurements and presenting results in a form required in industrial applications. The derived conclusions can be used as guidelines for preparation of industrial applicable construction of tomograph.

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17

Abubakar, A. "Uncertainty Analysis for the Measurement of Oil-Water Flow Parameters, Part II: Pressure Drop." Nigerian Journal of Technological Research 15, no. 1 (April 30, 2020): 1–7. http://dx.doi.org/10.4314/njtr.v15i1.1.

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The need to ensure qualitative and reliable measurement of pressure drop of the oil-water flow cannot be over emphasized. In this regard, this study focused on the investigation of uncertainty in the measurement of pressure drop of oil-water flow in different acrylic pipe inclinations (0, +5ᴼ, +10ᴼ and -5ᴼ) and diameters (30.6-, 55.7- and 74.7-mm ID). The working fluids were tap water and mineral-based hydraulic oil (Shell Tellus S2 V 15), with medium viscosity and density of 24 cP and 872 kgm-3 respectively while the interfacial tension between the water and the oil was 12.9 mN/m at 25 ᴼC. The selected flow conditions were 0.5 and 1.0 m/s mixture velocities each at 0.1, 0.5 and 0.9 input water volume fractions. The repeatability, accuracy of the pressure transmitter, flow rate of the oil-water mixture and holdup (particularly for the inclined flow) were the sources of errors in the measurement of the pressure drop. The results showed that the average relative uncertainties in the pressure drop in 30.6-mm ID pipe were ±4.6 %, ±10.8 %, ±11.2 % and ±10.8 % in the 0ᴼ, +5ᴼ, +10ᴼ and -5ᴼ inclined flows respectively. Similarly, the average relative uncertainties in the pressure drop in the horizontal 55.7-mm and 74.7-mm ID pipes were ±5.7 % and ±7.5 % respectively. The largest contribution to the uncertainty in the pressure drop came from the flow rate and water holdup in the horizontal and inclined pipes respectively. The least contribution in both horizontal and inclined pipes came from the accuracy of the pressure transmitter. Key words: Oil-water flow; Pressure drops; Standard uncertainty, Combined standard uncertainty; Expanded uncertainty

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18

Dong, F., C. Tan, W. Li, and F. S. Zhang. "Flow rate measurement of oil-water two-phase flow based on V-cone flow meter." Journal of Physics: Conference Series 147 (February 1, 2009): 012059. http://dx.doi.org/10.1088/1742-6596/147/1/012059.

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19

Rajan, V. S. V., R. K. Ridley, and K. G. Rafa. "Multiphase Flow Measurement Techniques—A Review." Journal of Energy Resources Technology 115, no. 3 (September 1, 1993): 151–61. http://dx.doi.org/10.1115/1.2905987.

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This paper is a review of current techniques available for measuring the velocity and composition in multiphase streams, to obtain the mass flow rate of the individual phases. An extensive literature search was conducted on the topic and related areas of interest. The major difficulty in measuring both the velocity and composition of multiphase streams is in dealing with the wide variety of flow regimes which are possible in multiphase flow in pipes. A device which is suitable for accurate velocity measurement in multiphase flows is not commercially available. However, if the flow is well mixed, it should be possible to calibrate a simple device, such as a nozzle or a venturi, to provide accurate total volumetric flow rates. Several commercial in-line static mixing devices are suitable for low gas concentrations (≤ 10 percent) and with superficial gas velocities higher than 10 m/s. For lower gas velocities and high gas concentrations, the suitability of these in-line mixers will have to be further assessed experimentally. Other techniques such as cross-correlation are known for two-phase flow velocity measurements, and the results of these applications look promising. A multiphase compositional meter to monitor the concentration of oil, water, and gas phases flowing in a pipeline, used in combination with a suitable homogenizer and a velocity meter, would facilitate measurement of the mass flow rates of the individual phases. Further work must be done to develop this concept.

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20

Zhang, Jun, Wei Wang, Hong Mei Tang, Xian Hua Li, and Chun Bao Fu. "Analysis of Pipeline Dynamic Flow Signal Coupling in Hydraulic System." Applied Mechanics and Materials 397-400 (September 2013): 2161–66. http://dx.doi.org/10.4028/www.scientific.net/amm.397-400.2161.

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The dynamic measurement of the high pressure side flow in hydraulic system is still one of the important and difficult problems in hydraulic test technique. In order to solve the dynamic coupling mechanism between main and bypass oil-way fluid flow signals in the bypass flow measurement method, hydraulic system software was used to analysis the problem in this paper, the dynamic coupling relationship between main and bypass oil-way fluid flow signals were obtained. Finally verify the feasibility of the bypass flow measurement method.

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21

Wylie, S. R., A. Shaw, and A. I. Al-Shamma'a. "RF sensor for multiphase flow measurement through an oil pipeline." Measurement Science and Technology 17, no. 8 (July 13, 2006): 2141–49. http://dx.doi.org/10.1088/0957-0233/17/8/013.

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22

Medeiros, K. A. R., C. R. H. Barbosa, and E. C. de Oliveira. "Flow Measurement by Piezoelectric Accelerometers: Application in the Oil Industry." Petroleum Science and Technology 33, no. 13-14 (July 18, 2015): 1402–9. http://dx.doi.org/10.1080/10916466.2015.1044613.

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23

Ismail, I., J. C. Gamio, S. F. A. Bukhari, and W. Q. Yang. "Tomography for multi-phase flow measurement in the oil industry." Flow Measurement and Instrumentation 16, no. 2-3 (April 2005): 145–55. http://dx.doi.org/10.1016/j.flowmeasinst.2005.02.017.

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24

Lakshmanan, Susithra, Wessenu A. Maru, Daniel J. Holland, Mick D. Mantle, and Andy J. Sederman. "Measurement of an oil–water flow using magnetic resonance imaging." Flow Measurement and Instrumentation 53 (March 2017): 161–71. http://dx.doi.org/10.1016/j.flowmeasinst.2016.04.001.

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25

Bonilla-Riaño, A., H. F. Velasco-Peña, A. C. Bannwart, H. M. Prasser, and O. M. H. Rodriguez. "Water film thickness measurement system for oil-water pipe flow." Flow Measurement and Instrumentation 66 (April 2019): 86–98. http://dx.doi.org/10.1016/j.flowmeasinst.2019.02.007.

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26

Damasceno, Magalí Araújo, Janaina Karla de Medeiros Penha, Nivaldo Ferreira da Silva Junior, Raimundo Nonato B. Felipe, Renata Carla Tavares dos Santos Felipe, and Gilson Gomes de Medeiros. "Influence of the temperature, pressure and viscosity on the oil measurement with turbine type measurers." Brazilian Archives of Biology and Technology 49, spe (January 2006): 65–72. http://dx.doi.org/10.1590/s1516-89132006000200011.

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The flow measurement of liquids and gases is a necessity in many industrial applications. There is a great amount of measurers for such purpose, as, for example, the coriolis, positive displacement and type turbine measurers. A measurer sufficiently used for the oil flow measurement is the turbine type, because it uses the proper extracted energy of the measured flow for its functioning, moreover is also used as standard for the calibration of other measurers. For this reason, it is important to study the parameters that influence the measurement process for turbine measurers. In Brazil, to measure the volume of oil, regardless the type of measurer, it is necessary to observe "Portaria Conjunta Nº. 1", of June 19, 2000, that approved the Technical Regulation of Measurement of Oil and Natural Gas, establishing the minimum conditions and requirements for the systems of oil and natural gas measurement, in order to get a measurement standard. As such, the present work has the objective of determining parameters that influence in the measurement of oil volumes using turbine measurers.

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27

Li, X., Z. L. Ding, and F. Yuan. "Application of Wavelet Analysis for Online Measurement of Crude Oils." Key Engineering Materials 295-296 (October 2005): 417–22. http://dx.doi.org/10.4028/www.scientific.net/kem.295-296.417.

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The correlation method had once been considered as one of the best methods for the measurement of multiphase flow. However, if the behavior of flow does not fit the ergodic random process, the measured cross correlation plot will have a gross distortion when the different components of flow do not pervade within one another to the full extent. We measured a variety of parameters of three phase oil/water/gas flow in an oil pipeline. The change of flow pattern is so complex that the measured signals are always contaminated by stochastic noises. The weak signals are very easily covered by the noise so that it will result in great deviation. Wavelet transformation is an analytical method of both time and frequency domain. The method can achieve signal decomposition and location in time and frequency domain through adjustment and translation of scale. An LMS algorithm in wavelet transform is studied for denoising the signals based on the use of a novel smart capacitive sensor to measure three phase oil/water/gas flow in oil pipeline. The results of simulation and data processing by MATLAB reveal that wavelet analysis has better denoising effects for online measurement of crude oils with high measurement precision and a wide application range.

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28

Severin Hansen, Dennis, Stefan Jespersen, Mads Valentin Bram, and Zhenyu Yang. "Uncertainty Analysis of Fluorescence-Based Oil-In-Water Monitors for Oil and Gas Produced Water." Sensors 20, no. 16 (August 8, 2020): 4435. http://dx.doi.org/10.3390/s20164435.

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Offshore oil and gas facilities are currently measuring the oil-in-water (OiW) concentration in the produced water manually before discharging it into the ocean, which in most cases fulfills the government regulations. However, as stricter regulations and environmental concerns are increasing over time, the importance of measuring OiW in real-time intensifies. The significant amount of uncertainties associated with manual samplings, that is currently not taken into consideration, could potentially affect the acceptance of OiW monitors and lower the reputation of all online OiW measurement techniques. This work presents the performance of four fluorescence-based monitors on an in-house testing facility. Previous studies of a fluorescence-based monitor have raised concerns about the measurement of OiW concentration being flow-dependent. The proposed results show that the measurements from the fluorescence-based monitors are not or insignificantly flow-dependent. However, other parameters, such as gas bubbles and droplet sizes, do affect the measurement. Testing the monitors’ calibration method revealed that the weighted least square is preferred to achieve high reproducibility. Due to the high sensitivity to different compositions of atomic structures, other than aromatic hydrocarbons, the fluorescence-based monitor might not be feasible for measuring OiW concentrations in dynamic separation facilities with consistent changes. Nevertheless, they are still of interest for measuring the separation efficiency of a deoiling hydrocyclone to enhance its deoiling performance, as the separation efficiency is not dependent on OiW trueness but rather the OiW concentration before and after the hydrocyclone.

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29

Ren, Weikai, An Zhao, and Ningde Jin. "Void Fraction Measurement of Oil–Gas–Water Three-Phase Flow Using Mutually Perpendicular Ultrasonic Sensor." Sensors 20, no. 2 (January 15, 2020): 481. http://dx.doi.org/10.3390/s20020481.

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The complex flow structure and interfacial effect in oil–gas–water three-phase flow have made the void fraction measurement a challenging problem. This paper reports on the void fraction measurement of oil–gas–water three-phase flow using a mutually perpendicular ultrasonic sensor (MPUS). Two pairs of ultrasonic probes are installed on the same pipe section to measure the void fraction. With the aid of the finite element method, we first optimize the emission frequency and geometry parameters of MPUS through examining its sensitivity field distribution. Afterward, the oil–gas–water three-phase flow experiment was carried out in a vertical upward pipe with a diameter of 20 mm to investigate the responses of MPUS. Then, the void fraction prediction models associated with flow patterns (bubble flow, slug flow, and churn flow) were established. Compared to the quick closing valves, MPUS obtained a favorable accuracy for void fraction measurement with absolute average percentage error equaling 8.983%, which indicates that MPUS can satisfactorily measure the void fraction of oil–gas–water three-phase flow.

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30

Zhang, Xiang, Yang Hong, Guang Lin Wang, Dong Xiang Shao, and Li Sun. "HLP Type Hydraulic Oil Analysis for Meso-Scale Hole Measurement." Key Engineering Materials 667 (October 2015): 427–32. http://dx.doi.org/10.4028/www.scientific.net/kem.667.427.

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HLP type hydraulic oil has wide application in aerospace field. The existing measurement method of Laval nozzle throat diameter efficiency is low, and has the potential to cut parts surface. Therefore, a non-contact throat diameter measuring method based on the hydraulic oil is proposed. Then the flow field is simulated, and measurement parameters are calculated. The flow field analysis results show that this method is suitable for measuring Laval nozzle throat diameter.

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31

Glebova, E. V., A. T. Volokhina, and E. A. Polikakhina. "Investigation of the Use of Ultrasonic Flow Meters at Oil Refining Process Unit." Occupational Safety in Industry, no. 12 (December 2020): 7–11. http://dx.doi.org/10.24000/0409-2961-2020-12-7-11.

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It is known that changes in the flow rate of the medium can directly affect the safety of the process of refining oil and petroleum products. Therefore, the use of high-precision flow meters is one of the safety barriers to prevent possible accidents and incidents. Unfortunately, the task of parametric measurement of the consumption of oil and petroleum products before and after their processing in most cases causes certain difficulties. For this reason, each specific measurement task should be approached from a different perspective, offering different means and methods of measurement, allowing to achieve the most reliable and accurate data on the measured flow rate. Operating conditions at the oil refineries place high demands on flow meters. Conventional orifice flow meters, which are often used to measure flow in the oil refineries, have certain disadvantages: they require frequent maintenance, process interruptions during installation, cause pressure losses in the pipe. Based on the experience of foreign companies in replacing insertion flow meters with clamp-on flow meters, it was decided to use non-invasive (non-contact) flow meters for medium measurement. The advantages of these flow meters are that there is no need to cut pipes, which practically eliminates the risk of leaks occurrence during installation. Also, the ultrasonic flow meter does not have direct contact with the measured medium, which allows avoiding contamination of both the flow meter itself and the medium, as a result, increasing the accuracy and durability of flow measurement at the site. Research objectives: substantiation of the possibility of operation of an ultrasonic flow meter at the oil refining site, recommendations for the use of various sensors, as well as selection of the optimal installation site for the device. The flow rate readings matched the previously established readings taken from the orifice meters. As a result, it is concluded that the ultrasonic flow meters can be used to measure the flow rate of stripped oil.

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32

Zhang, Jun, Yong Wu, Hong Mei Tang, Chun Ren Tang, and Xian Hua Li. "Study on Dynamic Characteristic in Hydraulic System Based on Bypass Method by the AMESim." Applied Mechanics and Materials 703 (December 2014): 298–302. http://dx.doi.org/10.4028/www.scientific.net/amm.703.298.

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s. At present, based on the bypass method to measurement the dynamic of the high pressure side flow in hydraulic system became more and more. In order to analysis the dynamic characteristics, the bypass method measurement system flow schematic was introduced in this paper, the dynamic flow of the main oil and the system was obtained by using dynamic flow of the side oil. Meanwhile, the dynamic pressure of the main oil was obtained by using dynamic pressure of the side oil. From the results of numerical analysis indicates that it is feasible to use the bypass method to get the characteristics of the dynamic flow and dynamic pressure in the system.

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Huo, Xiaokai, Weitao Sun, Fengjiang He, Zhe Yang, and Yuanping Peng. "Coupling Analysis of Low-Speed Multiphase Flow and High-Frequency Electromagnetic Field in a Complex Pipeline Structure." Mathematical Problems in Engineering 2014 (2014): 1–9. http://dx.doi.org/10.1155/2014/508571.

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Accurate estimation of water content in an oil-water mixture is a key technology in oil exploration and production. Based on the principles of the microwave transmission line (MTL), the logging probe is an important water content measuring apparatus. However, the effects of mixed fluid flow on the measurement of electromagnetic field parameters are rarely considered. This study presents the coupling model for low-speed multiphase flow and high-frequency electromagnetic field in a complex pipeline structure. We derived theS-parameter equations for the stratified oil/water flow model. The corresponding relationship between theS-parameters and water holdup is established. Evident coupling effects of the fluid flow and the electromagnetic field are confirmed by comparing the calculatedS-parameters for both stratified and homogeneous flow patterns. In addition, a multiple-solution problem is analyzed for the inversion of dielectric constant from theS-parameters. The most sensitive phase angle range is determined to improve the detection of variation in the dielectric constant. Suggestions are proposed based on the influence of the oil/water layer on measurement sensitivity to optimize the geometric parameters of a device structure. The method proposed elucidates how accuracy and sensitivity can be improved in water holdup measurements under high water content conditions.

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Chen, Feng Yun, and Wei Min Liu. "Research on Measurement of Void Fraction for Vertically Rising Pipes by Optical Fiber Probe." Advanced Materials Research 361-363 (October 2011): 671–75. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.671.

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A way of measuring the average cross-sectional void fraction for vertically rising oil pipes by using closing valves quickly and optical fiber probe has been researched. Experiments were performed in oil-gas two-phase flow and the range of the average void fraction is 0.1～0.5. The relationship between average cross-sectional void fraction of a oil-gas two-phase flow and pipe’s center void fraction in vertically rising oil pipes, for different pipe diameters and varying oil flow, is obtained. An exponential model of average void fraction is also obtained with reference to Bankoff’s[1] variable density model. It is found that local void fraction reduces from center in radial direction and the local void fraction maximum value appears in the pipe’s center.

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Bonilla Riaño, Adriana, Hugo Fernando Velasco Peña, Oscar Mauricio Hernandez Rodriguez, and Antonio Carlos Bannwart. "High spatial and temporal resolution film thickness planar sensor: comparison of geometries." Sensor Review 39, no. 1 (January 21, 2019): 78–86. http://dx.doi.org/10.1108/sr-08-2017-0177.

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Purpose The purpose of this paper is to study planar sensor geometries for the measurement of film thickness in a viscous oil–water flow. The study is relevant due to there are only a few measurement techniques for oil-water flow and these techniques involve oil with low viscosity (close to the water viscosity). Specifically, some techniques have been used in the studies of annular flow (gas–liquid and liquid–liquid flows), but applications in other flow patterns were not encountered. Design/methodology/approach Different sensor geometries were numerically simulated to compare their characteristics and choose the best to measure the water film thickness in the oil–water flow through an impedance-based technique. Finite element method was used for resolving the tridimensional electric field over each sensor. The compared characteristics were the penetration depth, the sensitivity, the minimum spatial resolution (high spatial resolution) and the quasi-linear curve. Findings The best geometry tested has a spatial resolution of 2 × 2 mm, a penetration depth of 700 µm and a quasi-linear response in the measuring range. This geometry was tested by means of conductance and capacitance static experiments. From these experiments, it could be determined that conductance and the capacitance systems are promising for measuring water film thickness in an oil–water flow. Originality/value Several measurement techniques such as micro-PIV, planar laser-induced fluorescence and planar conductive or capacitive sensors that are supposed to be adaptable to the liquid–liquid flow have been proposed recently. Micro-PIV and planar-induced fluorescence need transparent pipes and fluids. On the other hand, conductive or capacitive methods have been only applied to low viscosity fluids. In that context, this paper proposes to study a new technique for non-intrusive measurement of the liquid-liquid flow. The main goal is the validation of the new planar sensor as a reference tool for the development of instrumentation for oilfield application.

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Yu, Han, Chao Tan, and Feng Dong. "Measurement of oil fraction in oil-water dispersed flow with swept-frequency ultrasound attenuation method." International Journal of Multiphase Flow 133 (December 2020): 103444. http://dx.doi.org/10.1016/j.ijmultiphaseflow.2020.103444.

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A. Kendoush, Abdullah, Hameed B. Mahood, and Ibrahim G. Fiadh. "Volume Fraction Measurement in Crude Oil-Water Two-Phase Mixture using a Neutron Beam." Oriental Journal of Physical Sciences 2, no. 2 (December 25, 2017): 57–63. http://dx.doi.org/10.13005/ojps02.02.02.

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A neutron beam has been used to measure the volume fraction of crude oil in water of non- flow two-phase mixture experimentally.241Am-Be neutron source were used with an activity of 3.7x104 MBq. The volume fraction was simulated by using small plastic tubes filled with oil and immersed in non-flow water tube. The results show that it is feasible to measure the volume fraction of crude oil in a crude oil-water mixture.

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Shang, Ying, Xiao Hui Liu, Chang Wang, Bao Quan Sun, Gan Li, Wen An Zhao, Guo Yu Zhang, Jing Sheng Lv, and Wei Song Zhao. "Research of Optical Fiber Fluid Flow Monitoring System Using Flow-Induced Pipe Vibration in the Oil Production." Advanced Materials Research 616-618 (December 2012): 996–99. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.996.

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In the oil field development and production, fluid flow is an extremely important parameter which determines the transmission characteristics of the oil production, real-time monitoring of fluid flow parameter provides a scientific basis for oil and gas optimization exploration and increase of reservoir recovery. A method for interrogating fiber optic sensors using flow-induced pipe vibration is proposed, then the fixed relationship between standard deviation of pipe wall’s vibration induced by fully developed turbulence and mean flow rate is determined.The advantage of this method is applicable to small flow measurement with non-intrusively.

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Garrison, T. J., E. Manceau, and D. E. Nikitopoulos. "Skin Friction Measurements in a Gas-Liquid Pipe Flow Via Optical Interferometry." Journal of Fluids Engineering 120, no. 2 (June 1, 1998): 303–10. http://dx.doi.org/10.1115/1.2820649.

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An instrument for the measurement of wall shear stress in two-phase flows is described. The device, termed a Laser Interferometer Skin Friction (LISF) meter, determines the wall shear by optically measuring the time rate of thinning of a thin oil film placed on the wall of the flow channel. The LISF meter has proven to be a valuable tool for measurement of wall shear in single-phase gaseous flows but, to date, had not been applied to liquid or gas-liquid flows. This paper describes modifications to the LISF meter developed to facilitate its use in two-phase flows. The instrument’s configuration, governing theory, and data reduction procedure are described. Additionally, results of validation experiments for a single-phase water flow are presented, which demonstrate the instrument’s ability to accurately measure wall shear. Measurements are also presented for two-phase, water-air flows in a duct of square cross section at various superficial gas and liquid velocities within the bubbly flow regime. Results of the measurements confirm previous observations that the addition of a very small amount of the gaseous phase increases the wall shear significantly over that in a single-phase water flow. The two-phase wall shear saturates to a maximum and then declines again as the superficial gas velocity is increased. The peak two-phase wall shear increases as the liquid superficial velocity is decreased. These trends are qualitatively in agreement with previous measurements obtained in pipes using an electrochemical technique.

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Pourabdollah, Kobra, and Bahram Mokhtari. "Flow rate measurement of individual oil well using multivariate thermal analysis." Measurement 44, no. 10 (December 2011): 2028–34. http://dx.doi.org/10.1016/j.measurement.2011.08.013.

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WASHIO, Seiichi, Satoshi TAKAHASHI, and Satoshi YAMAGUCHI. "Measurement of Transiently Changing Flow Rates in Oil Hydraulic Column Separation." JSME International Journal Series B 39, no. 1 (1996): 51–56. http://dx.doi.org/10.1299/jsmeb.39.51.

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King, N. W. "Building a new National Standard for oil and multiphase flow measurement." Flow Measurement and Instrumentation 3, no. 2 (January 1992): 59–63. http://dx.doi.org/10.1016/0955-5986(92)90001-l.

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Xu, Zhuoqun, Fan Wu, Xinmeng Yang, and Yi Li. "Measurement of Gas-Oil Two-Phase Flow Patterns by Using CNN Algorithm Based on Dual ECT Sensors with Venturi Tube." Sensors 20, no. 4 (February 21, 2020): 1200. http://dx.doi.org/10.3390/s20041200.

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In modern society, the oil industry has become the foundation of the world economy, and how to efficiently extract oil is a pressing problem. Among them, the accurate measurement of oil-gas two-phase parameters is one of the bottlenecks in oil extraction technology. It is found that through the experiment the flow patterns of the oil-gas two-phase flow will change after passing through the venturi tube with the same flow rates. Under the different oil-gas flow rate, the change will be diverse. Being motivated by the above experiments, we use the dual ECT sensors to collect the capacitance values before and after the venturi tube, respectively. Additionally, we use the linear projection algorithm (LBP) algorithm to reconstruct the image of flow patterns. This paper discusses the relationship between the change of flow patterns and the flow rates. Furthermore, a convolutional neural network (CNN) algorithm is proposed to predict the oil flow rate, gas flow rate, and GVF (gas void fraction, especially referring to sectional gas fraction) of the two-phase flow. We use ElasticNet regression as the loss function to effectively avoid possible overfitting problems. In actual experiments, we compare the Typical-ECT-imaging-based-GVF algorithm and SVM (Support Vector Machine) algorithm with CNN algorithm based on three different ECT datasets. Three different sets of ECT data are used to predict the gas flow rate, oil flow rate, and GVF, and they are respectively using the venturi front-based ECT data only, while using the venturi behind-based ECT data and using both these data.

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Randhawa, S. S., A. K. Ganju, and R. P. Bajpai. "Development of a heating reactor for a continuous flow-through application in urea measurement." Journal of Automated Methods and Management in Chemistry 25, no. 6 (2003): 129–32. http://dx.doi.org/10.1155/s1463924603000221.

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In most biochemical analyses, a flow-through heating arrangement is needed to reduce the reaction time or maintain a constant temperature. A rectangular reactor is described that is constructed of aluminium, is hollow inside and is filled with silicone oil. The glass coil through which the solution flows is immersed in the silicone oil. The heater, a Peltier-effect heat pump, on one side and the temperature sensor on the other side of the reactor body are embedded for heating and temperature control. The brief performance evaluation of the reactor is discussed by measuring the absorbance of urea concentration at different temperatures.

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O'Neill, Keelan T., Lorenzo Brancato, Paul L. Stanwix, Einar O. Fridjonsson, and Michael L. Johns. "Two-phase oil/water flow measurement using an Earth’s field nuclear magnetic resonance flow meter." Chemical Engineering Science 202 (July 2019): 222–37. http://dx.doi.org/10.1016/j.ces.2019.03.018.

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Jia, Yong Feng, Li Chen Gu, and Qing Qing Tian. "Soft-Sensing Method for Flow of the Variable Speed Drive Constant Pump." Applied Mechanics and Materials 318 (May 2013): 55–58. http://dx.doi.org/10.4028/www.scientific.net/amm.318.55.

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According to characteristics of permanent magnet synchronous servo motor driven constant pump hydraulic system, and relevant parameters of the motor, the pump and the oil, an indirect measurement system for flow based on soft-sensing model is established. The measurement of the output flow of constant pump is realized easily by measuring the speed of the motor. And the accuracy of measurement of the model has been improved with the oil viscosity-temperature behavior, viscosity-pressure characteristic and the conditions fuzzy compensation coefficient. Experimental results show that the soft-sensing model is of enough accuracy and has an excellent response.

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Godoy-Alcántar, J. Martín, Guillermo Cervantes-Martínez, Juan Antonio Cruz-Maya, Miguel Ángel Hernández-Buenfil, and Israel Ramírez-Antonio. "Sistema de medición de flujo multifásico mediante tecnología ciclónica GLCC para aforo de pozos petroleros." Ingeniería, investigación y tecnología 9, no. 4 (October 1, 2008): 293–311. http://dx.doi.org/10.22201/fi.25940732e.2008.09n4.022.

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Henry, M. P., M. S. Tombs, and F. B. Zhou. "Towards assessing online uncertainty for three-phase flow metering in the oil and gas industry." Journal of Sensors and Sensor Systems 3, no. 1 (April 22, 2014): 97–103. http://dx.doi.org/10.5194/jsss-3-97-2014.

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Abstract. A new three-phase (oil/water/gas) flow metering system has been developed for use in the oil and gas industries, based on Coriolis mass flow metering. To obtain certification for use in the Russian oil and gas industries, trials have taken place at the UK and Russian national flow laboratories, NEL in Glasgow and VNIIR in Kazan, respectively. The metrology of three-phase flow is complex, and the uncertainty of each measurement varies dynamically with the operating point, as well as the metering technology, and other aspects. To a limited extent this is reflected in the error limits allowed in national standards, which may vary with operating point. For example, the GOST standard allows errors in the oil flow rate of ±6% for water cuts of less than 70%, which is increased to ±15% for water cuts between 70 and 95%. The provision of online uncertainty for each measurement, for example in accordance with the British Standard BS-7986, would be highly desirable, allowing the user to observe in real time variations in measurement quality. This paper will discuss how an online uncertainty assessment could be implemented in the Coriolis meter-based system.

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Shi, Jun-Feng, Feng Deng, Li-Zhi Xiao, Hua-Bing Liu, Feng-Qin Ma, Meng-Ying Wang, Rui-Dong Zhao, Shi-Wen Chen, Jian-Jun Zhang, and Chun-Ming Xiong. "A proposed NMR solution for multi-phase flow fluid detection." Petroleum Science 16, no. 5 (September 25, 2019): 1148–58. http://dx.doi.org/10.1007/s12182-019-00367-3.

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Abstract In the petroleum industry, detection of multi-phase fluid flow is very important in both surface and down-hole measurements. Accurate measurement of high rate of water or gas multi-phase flow has always been an academic and industrial focus. NMR is an efficient and accurate technique for the detection of fluids; it is widely used in the determination of fluid compositions and properties. This paper is aimed to quantitatively detect multi-phase flow in oil and gas wells and pipelines and to propose an innovative method for online nuclear magnetic resonance (NMR) detection. The online NMR data acquisition, processing and interpretation methods are proposed to fill the blank of traditional methods. A full-bore straight tube design without pressure drop, a Halbach magnet structure design with zero magnetic leakage outside the probe, a separate antenna structure design without flowing effects on NMR measurement and automatic control technology will achieve unattended operation. Through the innovation of this work, the application of NMR for the real-time and quantitative detection of multi-phase flow in oil and gas wells and pipelines can be implemented.

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Wardhaugh, L. T., and D. V. Boger. "PIPELINE FLOW OF WAXY CRUDE OILS." APPEA Journal 32, no. 1 (1992): 405. http://dx.doi.org/10.1071/aj91032.

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The various methods for handling waxy crude oils at temperatures below the pour point have been difficult to assess quantitatively owing to the lack of reliable measurement techniques for properties such as the non-Newtonian viscosity and yield stress. Research undertaken at The University of Melbourne has been aimed at the development of reproducible measurement techniques for laboratory scale rheometers and, in so doing, has provided an understanding of the rheology of waxy oils that is applicable to the design and operation of waxy oil pipelines and handling systems and in understanding the startup behaviour of pipelines.The equilibrium flow properties of waxy oils are determined by the shear and thermal history applied to the oil. In particular, the very strong shear history dependence influences the behaviour of pipelines servicing declining fields, leads to an over-estimation of the flowrate when conventional design methods are used, and provides a mechanism for wall deposition of wax that depends on the oil rheology rather than mass transfer mechanisms. Modified design methods are outlined for both laminar and turbulent flow which account for the effect of shear history and enable a quantifiable measure, under steady conditions, of the return on investment of alternative handling techniques such as the use of flow improver additives.Waxy crude oil that has been statically cooled develops solid-like character at temperatures below the pour point. The complex yielding process exhibits three distinct behaviours-yield, creep and fracture, each of which influences the startup behaviour of a gelled pipeline.

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