WO1995033980A1 - Mesure de densite et de debit d'un fluide multiphases - Google Patents

Mesure de densite et de debit d'un fluide multiphases Download PDF

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Publication number
WO1995033980A1
WO1995033980A1 PCT/GB1995/001221 GB9501221W WO9533980A1 WO 1995033980 A1 WO1995033980 A1 WO 1995033980A1 GB 9501221 W GB9501221 W GB 9501221W WO 9533980 A1 WO9533980 A1 WO 9533980A1
Authority
WO
WIPO (PCT)
Prior art keywords
pressure
fluid mixture
conduit
gas
flow rate
Prior art date
Application number
PCT/GB1995/001221
Other languages
English (en)
Inventor
Miroslav M. Kolpak
Terry J. Rock
Original Assignee
Atlantic Richfield Company
Arco British Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Atlantic Richfield Company, Arco British Limited filed Critical Atlantic Richfield Company
Publication of WO1995033980A1 publication Critical patent/WO1995033980A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid

Definitions

  • the present invention pertains to a differential pressure measurement system and method for measuring the flow rate and density of a mixture of gas and liquid and particularly useful in oil and gas production operations.
  • volumetric flow rate of the fluid mixture and the volumetric flow rate of one or both fluids in the mixture at particular points in such a mixture distribution system to control the flow to several injection wells and to maintain a desired gas to liquid ratio, for example.
  • the present invention provides an improved system and method for measuring the density of a multiphase fluid mixture and also the volumetric flow rate of the mixture and its phase components.
  • the present invention provides an improved system for measuring the density and the flow rate of a multiphase fluid mixture comprising gas and liquid.
  • a system for measuring the density of a multiphase fluid flowstream by measuring a pressure differential in the flowstream along a predetermined length of a vertical run of a conduit conducting the flowstream and also by measuring the pressure differential of the flowstream along a predetermined length of a horizontal run of the conduit to determine the pressure differential component which is due to friction flow losses.
  • an improved density measurement device for measuring the density of a multiphase fluid flowing through a substantially horizontal run of a conduit at a predetermined point in the conduit by measuring the differential pressure across the width or diameter of the conduit more accurately than with certain prior art devices.
  • the system for measuring the pressure differential across the conduit width or diameter includes spaced apart pressure transmitter devices which are effective to eliminate (a) errors due to changes in the liquid/gas interface in the pressure sensing device such as are experienced with so-called diaphragm type differential pressure transducers and (b) complicated runs of tubing required for installation, protection and effective operation of diaphragm type differential pressure measuring devices. Still further, the improved systems of the invention eliminate pressure biasing caused by the dynamic response of the pressure sensing tubes and diaphragm systems in prior art diaphragm type differential pressure measurement devices.
  • the present invention provides a device for measuring the density and flow rate of a multiphase fluid flow mixture which does not require a complicated densitometer such as the so-called gamma ray type. Elimination of the gamma ray type densitometer eliminates or reduces the requirements of a nuclear device safety program, such as wipe tests and procedures mandated by regulatory agencies. Other disadvantages of nuclear or gamma ray type densitometers include lack of sensitivity and large noise to signal ratio when measuring fluid density in a conduit which is conducting primarily gas.
  • the present invention provides an improved method for measuring the volumetric flow rate of the component phases (gas and liquid) in a multiphase fluid flowstream, which is particularly useful in certain operations such as injection of a water and gas mixture into a subterranean formation and in the production of petroleum liquids and/or gas wherein mixtures of both are emanating from an earth formation.
  • FIG. 1 is a somewhat schematic view of one embodiment of a system for measuring the density and flow rate of a multiphase fluid mixture
  • Figure 2 is a diagram showing another embodiment of a system for measuring the density and flow rate of a multiphase fluid mixture
  • Figure 3 is a cross-sectional view of the conduit and pressure transmitter arrangement for the embodiment of Figure
  • Figure 4 is a detail view of part of a pressure transmitter useful in the systems of the present invention.
  • Figure 5 is a section view taken generally along the line 5-5 of Figure 6;
  • Figure 6 is a longitudinal view, partially sectioned, of an alternate embodiment of a pressure transmitter.
  • Figure 7 is a somewhat schematic diagram of a second alternate embodiment of a system for measuring multiphase fluid mixtures.
  • FIG. 1 there is illustrated a system in accordance with the present invention, generally designated by the numeral 10, which is operable to measure the density and flow rate of a multiphase fluid mixture flowing through a conduit 12.
  • the conduit 12 has a vertical run or leg 14 and a horizontal run or leg 16 which are adapted to comprise part of the system 10.
  • a multiphase fluid mixture such as a mixture of natural gas and water, flows through the conduit 12 in the direction of the arrows indicated in Figure 1.
  • a so called static fluid mixing device 18 is preferably interposed in the conduit 12 upstream of certain parts of the system 10 to be described herein to assure uniform mixing of a gas/liquid mixture passing through the system.
  • the mixing device 18 may be of a type commercially available, for example, a type which is described in U.S.
  • a suitable static mixing device may also be of the type described in U.S. Patent 4,824,614 to J. A. Jones and issued April 25, 1989.
  • the static mixing device 18 should be disposed just upstream of the pressure and flow rate measuring components of the system 10, preferably no more than about 2.0 feet, when measuring a mixture of water and gas wherein the gas content is about twenty percent (20%) or less by volume of the total mixture.
  • the system 10 includes two spaced-apart pressure transmitters 20 disposed a distance L from each other along the vertical leg 14 of the conduit 12 and a second set of pressure transmitters 20 disposed apart the same distance L along the horizontal leg 16 of the conduit 12.
  • a conventional volumetric flowmeter 22 is interposed in the conduit 12 where indicated.
  • the flowmeter 22 may be of the so- called turbine type suitable for measuring a multiphase fluid mixture.
  • the pressure transmitters 20 are preferably of a type which generates or modifies an electrical signal in response to sensing a pressure in the conduit 12 at the location of the transmitters, respectively.
  • one type of pressure transmitter which may be suitable for the system 10 is of a type which utilizes a piezoelectric sensing element, such as available from SDR of Lenexa, Kansas as their type 534 MP.
  • Figure 4 illustrates certain details of one embodiment of a pressure transmitter generally of the type described above having a shank portion 23 and a pressure transmitting surface 25 formed thereon and which may be exposed to the fluid mixture flowing through conduit 12.
  • the pressure transmitter 20 having a pressure responsive surface 25 which may be mounted substantially coplanar with the inside wall of the conduit 12 so as to minimize flow disturbances and the resultant transmitter signal errors which may be incurred.
  • the output signals from the pressure transmitters of the system 10, comprising transmitters 20a, 20b, 20c and 20d, and the output signal from the flowmeter 22 may be processed by a suitable signal processing and computing device generally designated by the numeral 24.
  • the density of the fluid mixture flowing through the conduit 12 may be determined by applying the Bernoulli equation for the pressure differential between the respective sets of pressure transmitters as follows:
  • Equations (1) and (2) above define the pressure differential across the length L for frictional pressure losses in the conduit 12 and equation (2) includes an additional term which is the hydrostatic pressure of a column of length L of material having a density den in the vertical leg 14 of the conduit 12.
  • This equation (3) is particularly valid if the pipe diameter and pipe roughness are the same in both the vertical and horizontal legs 14 and 16 and the flow velocity is sufficient to minimize liquid fall back or plugging of the vertical leg.
  • the pressure differentials across the respective lengths L of the horizontal leg 16 and the vertical leg 14 are measured by the respective sets of pressure transmitters and a computation of the density, den, may be carried out by the signal processor and computer 24. Appropriate averaging or filtering techniques may be used as well as proper selection of transducer "zero" and “span” values to minimize signal bias. Still further, the flow rate of the multiphase fluid mixture may be measured directly by the flowmeter 22 and the flow rates of the components of liquid and gas in the fluid mixture can be calculated,as will be described hereinbelow, to determine, for example, if the desired gas-to-liquid ratio of fluid flow is being conducted through the system, or at least the volumetric flow rate of the liquid and the gas may be ascertained for accounting purposes.
  • the densities of the liquid and the gas are assumed or may be separately measured at the flow conditions in the system 10. For example, if the system 10 is used to inject a mixture of natural gas and water into an earth formation for storage of the gas and for use as a drive fluid for petroleum liquids in the formation, the densities of the liquid and gas may easily be ascertained.
  • the gas-to-liquid ratio (GLR) is the ratio of the volumetric flow rate of gas (Qg) divided by the total flow (Qg + Ql) where (Ql) is the liquid volumetric flow rate.
  • the gas-to-liquid ratio of the fluid mixture in the combined flowstream may be computed from the following equation:
  • dl and dg are the densities of the liquid and the gas, respectively, (in pounds per cubic foot). Accuracies in the range of about ten percent (10%) variance from actual values should be achievable over much of a practical gas-to-liquid ratio range including a range wherein the volumetric fraction of gas in the total mixture is up to about twenty percent (20%).
  • Qm is the volumetric flow rate measured by the flowmeter 22.
  • the system 10 for determining volumetric flow rates of liquid and gas in a multiphase fluid mixture is particularly advantageous in that the density of the fluid mixture is obtainable without the use of a nuclear type densitometer and the attendant maintenance and safety procedures that must accompany the use of such devices. Moreover, with the accuracy of the flowmeter 22 and the pressure transmitters 20a, 20b, 20c and 20d, measurement errors associated with certain other types of differential pressure transmitter or transducer devices are minimized.
  • the fluid friction factor is not required to be known in order to make a determination of the fluid mixture density when a set of pressure transmitters is disposed in a horizontal run of the system and spaced apart the same distance as the distance between the pressure transmitters of the vertical leg of the conduit.
  • the system 40 includes a generally horizontally extending cylindrical conduit 42 which, for sake of discussion, is in communication with a source of a fluid mixture comprising natural gas and water and is operable to conduct this fluid mixture to an injection well by way of a wellhead 44.
  • a flowmeter 22 is interposed in the conduit 42 and a set of pressure transmitters 20e and 2Of,similar to the transmitters in the system 10, are arranged opposed to each other along a vertical line 46 intersecting the central longitudinal axis 47 of the conduit 42, see Figure 3.
  • each of the pressure transmitters 20e and 20f are substantially coplanar with opposed planar surfaces 50 and 52 formed by respective filler or insert parts 54 and 56, which may be interposed in the conduit 42 as illustrated in Figures 2 and 3.
  • insert parts 54 and 56 may be faired into the surface of the interior of the conduit 42 at their inlet and discharge ends, respectively, to minimize turbulence in the flowstream of the fluid mixture passing through the conduit from a mixing device 18 to the flowmeter 22, for example.
  • the pressure transmitting surfaces 25 of the opposed transmitters 20e and 20f are spaced apart a vertical distance "d".
  • the density, den may be determined from the equation:
  • the pressure transmitters 20e and 20f may also be of a type illustrated in Figures 5 and 6. Referring to Figures 5 and 6. Referring to Figures 5 and 6.
  • a modified conduit 42 which has interposed therein opposed segments 66 and 68 which are pressure sensitive but which also conform to the shape of the inside wall 43 of the conduit 42 so as not to provide a flow restriction or a point of accumulation of debris.
  • the segments 66 and 68 which are pressure sensitive but which also conform to the shape of the inside wall 43 of the conduit 42 so as not to provide a flow restriction or a point of accumulation of debris.
  • the segments 66 and 68 may be flexible diaphragm members made of a suitable elastomeric material or made of material which, in response to deflection, emits an electrical signal.
  • the segments 66 and 68 define opposed cavities 70 and
  • the cavities 70 and 72 may be filled with a suitable pressure fluid which may be operable to transmit differential pressure forces to a pressure differential gauge or sensor 78 whose output signal may be transmitted to a signal processor and computer, not shown.
  • a suitable pressure fluid which may be operable to transmit differential pressure forces to a pressure differential gauge or sensor 78 whose output signal may be transmitted to a signal processor and computer, not shown.
  • the pressure transmitters utilized in conjunction with the present invention may be of a type manufactured by Camille Bauer, Inc., Tempe,
  • FIG. 7 there is illustrated another embodiment of a system in accordance with the present invention and generally designated by the numeral 90.
  • the system 90 is adapted to handle multiphase fluid flow wherein, from time to time, so-called slug flow is encountered and also wherein a relatively high gas fraction (as high as .99) may be encountered and further wherein the accuracy of measurement of the liquid and gas is required to be greater than the ten percent (10%) variance discussed for the systems 10 and 40.
  • the system 90 includes a fluid inlet conduit 92 connected to an enlarged diameter conduit part 94 which may have a plurality of spaced apart transverse baffles 96 interposed therein.
  • the baffles 96 extend substantially half the diameter of the conduit part 94 from the lower side thereof and are preferably perforated to thoroughly mix the fluid flowing through the conduit part 94. Accordingly, fluid flow leaving the conduit part 94 is essentially uniform even though the in-flow to the conduit part 94 may be in the so-called slug regime. Uniform liquid flow through the system 90 will provide for approximately five percent (5%) net oil measurement accuracy whereas slug flow will not provide such accuracy due to, among other things, rapid and large transient values in the differential pressure measurements.
  • Fluid flow leaving the enlarged diameter conduit part 94 enters a somewhat loop conduit arrangement comprising a smaller diameter horizontally extending conduit section 98 connected to a first vertical leg 100, a reverse horizontal leg 102, a second vertical leg 104 and a horizontal exit leg 106.
  • a suitable venturi 108 is interposed in the inlet leg 98 and a differential pressure transmitter arrangement including a differential pressure measurement device 110 is provided and connected to pressure transmitters 112 and 114.
  • the transmitter 114 is located approximately at the. throat of the venturi 108.
  • the differential pressure transmitter 110 is operable to send an appropriate signal to a signal processor and computer unit 116 similar to the units 24.
  • the vertical conduit leg 100 includes spaced apart pressure transmitters 120a and 120b which are suitably connected to a differential pressure signal transmitter device 122, also operably connected to the signal processor 116. Still further, the horizontal conduit leg 102 is provided with pressure transmitters 120c and 12Od which are suitably connected to a differential pressure signal transmitter 126, also operably connected to the processor 116.
  • the arrangement of the pressure transmitters 120a, 120b, 120c and 120d is similar to the arrangement of the pressure transmitters in the embodiment of Figure 1.
  • the system 90 further includes a suitable meter 130 for measuring the water fraction of the liquid mixture flowing through the system.
  • An inlet port 132 of the meter 130 is connected to the conduit 104 at a suitable flow mixing device 136.
  • a return port 138 is connected to a venturi 140 interposed in the conduit leg 104 to provide a pressure drop suitable to cause flow through the water fraction meter 130.
  • the water fraction meter 130 may be of a type similar to that described in U.S. Patent 5,157,339, issued October 20, 1992 to Bentley N. Scott, et al and assigned to the assignee of the present invention.
  • the system 90 includes a gas densitometer 144 adapted to measure a slipstream of gas taken through a conduit 146 from the top side of conduit part 94 and rejected to the system at the venturi 140.
  • the gas densitometer 144 may be of a type manufactured by Automation Products, Inc., Houston, TX, under the trademark Dynatrol.
  • the output signal from the gas densitometer 144 is also treated by the processor 116.
  • Fluid flow entering the conduit part 94 is made essentially uniform, then passes through the horizontal leg 98 and the venturi 108, then through the vertical leg 100, the horizontal leg 102, the vertical leg 104 and exits the system through the horizontal leg 106 which, in the view of Figure 7, is disposed behind the leg 98.
  • the differential pressure measurement arrangement including the transmitters 112 and 114 and the signal measurement and transmitter device 110 effectively comprises a flowmeter since the differential pressure measurement of the total flow is proportional to the density of the total flow times the flow velocity squared.
  • the cross sectional area of the pipe leg 98 may be easily determined and included in a calculation of the volumetric flow rate once the velocity has been determined based on the differential pressure measurement and the density measurement of the fluid flow from Equation (3) and the pressure differential measurements taken in the vertical leg 100 and the horizontal leg 102.
  • the systems 10, 40 and 90 may find several applications in measuring multiphase fluid mixtures.
  • the system 10 may be operated in conjunction with the liquid or gas outflow line from a liquid-gas separator vessel 60, Figure 1, (liquid outflow line shown) to determine whether or not gas or liquid carry-over is being experienced in the respective outflow lines.
  • the system 40 in Figure 2 is, as previously described, interposed in a conduit system for conducting a gas and liquid mixture to an injection well. By monitoring the density and gas-to-liquid ratio of the mixture flowing through the conduit 42, any change in the prescribed mixture may be detected and suitable adjustments to the inputs of the flowstream may be carried out.
  • Those skilled in the art will recognize that certain other applications of the systems 10, 40 and 90 may be advantageous.
  • the systems 10, 40 and 90 be constructed using conventional materials and components used in fluid flow measuring devices and including the components specifically identified above.

Abstract

On peut déterminer la densité d'un mélange de fluides multiphases (gaz et liquide) et le débit volumétrique du liquide et du gaz de ce mélange en mesurant la différence de pression hydrostatique sur un segment de section de conduite verticale ou horizontale, grâce à des capteurs de pression espacés en vis-à-vis sur le tronçon de conduite horizontale ou espacés verticalement sur un tronçon de conduite verticale. La différence de pression due à la seule pression hydrostatique peut aussi être déterminée sur le tronçon de conduite verticale par mesure de la différence de pression sur un segment de tronçon d'une conduite horizontale d'une longeur égale au segment servant aux mesures de différence de pression sur le tronçon vertical, pour éviter des calculs de la chute de pression due aux frottements. On peut déterminer les débits volumétriques du gaz et du liquide à partir des mesures de densité et du débit volumétrique du mélange de fluides.
PCT/GB1995/001221 1994-06-07 1995-05-26 Mesure de densite et de debit d'un fluide multiphases WO1995033980A1 (fr)

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US25513994A 1994-06-07 1994-06-07
US08/255,139 1994-06-07

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Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6155102A (en) * 1998-08-06 2000-12-05 Alberta Research Council Method and apparatus for use in determining a property of a multiphase fluid
US6272934B1 (en) 1996-09-18 2001-08-14 Alberta Research Council Inc. Multi-phase fluid flow measurement apparatus and method
GB2367138A (en) * 2000-07-21 2002-03-27 Lattice Intellectual Property A meter for measurement of multiphase fluids
US7562587B2 (en) 2007-11-03 2009-07-21 Schlumberger Technology Corporation Determination of density for metering a fluid flow
US7607358B2 (en) 2008-03-14 2009-10-27 Schlumberger Technology Corporation Flow rate determination of a gas-liquid fluid mixture
US7650799B2 (en) 2007-03-15 2010-01-26 Schlumberger Technology Corporation Method and apparatus for investigating a gas-liquid mixture
JP4599454B1 (ja) * 2009-09-07 2010-12-15 株式会社オーバル 容積式気液二相流量計及び多相流量計測システム
CN102121890A (zh) * 2010-12-16 2011-07-13 中南大学 一种用于灌浆工程中密度测量的自循环差压式密度计
US8027794B2 (en) 2008-02-11 2011-09-27 Schlumberger Technology Corporaton System and method for measuring properties of liquid in multiphase mixtures
US8694270B2 (en) 2007-12-05 2014-04-08 Schlumberger Technology Corporation Ultrasonic clamp-on multiphase flowmeter
US9031797B2 (en) 2007-09-18 2015-05-12 Schlumberger Technology Corporation Multiphase flow measurement
CN104880228A (zh) * 2014-02-28 2015-09-02 横河电机株式会社 多相流量计
JP2015161663A (ja) * 2014-02-28 2015-09-07 横河電機株式会社 多相流流量計
RU2632999C2 (ru) * 2015-12-15 2017-10-11 Ильшат Робертович Салимов Устройство для измерения параметров жидких сред в трубопроводе
RU2634081C2 (ru) * 2016-01-29 2017-10-23 Ильшат Робертович Салимов Устройство для измерения параметров газожидкостной смеси, добываемой из нефтяных скважин
CN108760569A (zh) * 2018-07-13 2018-11-06 孙玘凡 油水混合液密度及纯油流量测量装置及方法
WO2024020104A1 (fr) * 2022-07-19 2024-01-25 Saudi Arabian Oil Company Mesure de débits de fluides multiphases

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US4059744A (en) * 1976-12-08 1977-11-22 International Telephone And Telegraph Corporation Net oil computer or the like
US4225778A (en) * 1979-04-23 1980-09-30 International Telephone And Telegraph Corporation Flow detection system
US4261196A (en) * 1979-09-28 1981-04-14 Scheid Jr Charles H Method and apparatus for determining solids conveyed in a slurry moving in a pipe
US4417474A (en) * 1980-12-22 1983-11-29 Itt Densitometer
WO1991015738A1 (fr) * 1990-04-02 1991-10-17 Joram Agar Mesure amelioree d'un debit en deux ou trois phases
US5157339A (en) * 1991-04-16 1992-10-20 Atlantic Richfield Company Method for measuring water-oil mixtures with relatively high gas content
WO1993019347A1 (fr) * 1992-03-17 1993-09-30 Agar Corporation Limited Appareil et procede de mesure de debits de fluide a deux ou trois phases utilisant un ou plusieurs debitmetres cinetiques et un debitmetre volumetrique

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4059744A (en) * 1976-12-08 1977-11-22 International Telephone And Telegraph Corporation Net oil computer or the like
US4225778A (en) * 1979-04-23 1980-09-30 International Telephone And Telegraph Corporation Flow detection system
US4261196A (en) * 1979-09-28 1981-04-14 Scheid Jr Charles H Method and apparatus for determining solids conveyed in a slurry moving in a pipe
US4417474A (en) * 1980-12-22 1983-11-29 Itt Densitometer
WO1991015738A1 (fr) * 1990-04-02 1991-10-17 Joram Agar Mesure amelioree d'un debit en deux ou trois phases
US5157339A (en) * 1991-04-16 1992-10-20 Atlantic Richfield Company Method for measuring water-oil mixtures with relatively high gas content
WO1993019347A1 (fr) * 1992-03-17 1993-09-30 Agar Corporation Limited Appareil et procede de mesure de debits de fluide a deux ou trois phases utilisant un ou plusieurs debitmetres cinetiques et un debitmetre volumetrique

Cited By (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6272934B1 (en) 1996-09-18 2001-08-14 Alberta Research Council Inc. Multi-phase fluid flow measurement apparatus and method
US6155102A (en) * 1998-08-06 2000-12-05 Alberta Research Council Method and apparatus for use in determining a property of a multiphase fluid
GB2367138A (en) * 2000-07-21 2002-03-27 Lattice Intellectual Property A meter for measurement of multiphase fluids
GB2367138B (en) * 2000-07-21 2004-07-07 Lattice Intellectual Property A meter for the measurement of multiphase fluids and wet gas
US7650799B2 (en) 2007-03-15 2010-01-26 Schlumberger Technology Corporation Method and apparatus for investigating a gas-liquid mixture
US9031797B2 (en) 2007-09-18 2015-05-12 Schlumberger Technology Corporation Multiphase flow measurement
US7987733B2 (en) 2007-11-03 2011-08-02 Schlumberger Technology Corporation Determination of density for metering a fluid flow
US7562587B2 (en) 2007-11-03 2009-07-21 Schlumberger Technology Corporation Determination of density for metering a fluid flow
US8694270B2 (en) 2007-12-05 2014-04-08 Schlumberger Technology Corporation Ultrasonic clamp-on multiphase flowmeter
US8027794B2 (en) 2008-02-11 2011-09-27 Schlumberger Technology Corporaton System and method for measuring properties of liquid in multiphase mixtures
US7607358B2 (en) 2008-03-14 2009-10-27 Schlumberger Technology Corporation Flow rate determination of a gas-liquid fluid mixture
JP2011058838A (ja) * 2009-09-07 2011-03-24 Oval Corp 容積式気液二相流量計及び多相流量計測システム
CN102782462A (zh) * 2009-09-07 2012-11-14 株式会社奥巴尔 容积式气液二相流量计及多相流量计测系统
WO2011027606A1 (fr) * 2009-09-07 2011-03-10 株式会社オーバル Débitmètre à déplacement positif pour écoulement biphasique gaz-liquide et système permettant la mesure des débits de plusieurs phases
JP4599454B1 (ja) * 2009-09-07 2010-12-15 株式会社オーバル 容積式気液二相流量計及び多相流量計測システム
CN102121890A (zh) * 2010-12-16 2011-07-13 中南大学 一种用于灌浆工程中密度测量的自循环差压式密度计
CN104880228A (zh) * 2014-02-28 2015-09-02 横河电机株式会社 多相流量计
JP2015161663A (ja) * 2014-02-28 2015-09-07 横河電機株式会社 多相流流量計
RU2632999C2 (ru) * 2015-12-15 2017-10-11 Ильшат Робертович Салимов Устройство для измерения параметров жидких сред в трубопроводе
RU2634081C2 (ru) * 2016-01-29 2017-10-23 Ильшат Робертович Салимов Устройство для измерения параметров газожидкостной смеси, добываемой из нефтяных скважин
CN108760569A (zh) * 2018-07-13 2018-11-06 孙玘凡 油水混合液密度及纯油流量测量装置及方法
WO2024020104A1 (fr) * 2022-07-19 2024-01-25 Saudi Arabian Oil Company Mesure de débits de fluides multiphases

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