WO1991005135A1 - Appareil mesureur des fractions de phase - Google Patents

Appareil mesureur des fractions de phase Download PDF

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Publication number
WO1991005135A1
WO1991005135A1 PCT/GB1990/001499 GB9001499W WO9105135A1 WO 1991005135 A1 WO1991005135 A1 WO 1991005135A1 GB 9001499 W GB9001499 W GB 9001499W WO 9105135 A1 WO9105135 A1 WO 9105135A1
Authority
WO
WIPO (PCT)
Prior art keywords
chamber
passage
pipe
defining
fluid
Prior art date
Application number
PCT/GB1990/001499
Other languages
English (en)
Inventor
Nicholas William King
Original Assignee
The Secretary Of State For Trade And Industry In Her Britannic Majesty's Government Of The United Kingdom Of Great Britain And Northern Ireland
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 The Secretary Of State For Trade And Industry In Her Britannic Majesty's Government Of The United Kingdom Of Great Britain And Northern Ireland filed Critical The Secretary Of State For Trade And Industry In Her Britannic Majesty's Government Of The United Kingdom Of Great Britain And Northern Ireland
Publication of WO1991005135A1 publication Critical patent/WO1991005135A1/fr

Links

Classifications

    • 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
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • E21B49/086—Withdrawing samples at the surface
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • 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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/107—Locating fluid leaks, intrusions or movements using acoustic means
    • 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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
    • 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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F23/00—Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm
    • G01F23/30—Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm by floats

Definitions

  • the present invention relates to apparatus for measuring the various fractions of a multi-phase (in which term is included multi-component) flow system, and is particularly concerned with multi-phase flow systems containing gas, oil and water such as issue from oil wells.
  • the total flow rate is measured, and a-sample of the total flow is then diverted from the main flow, passed through a separator where the gaseous and liquid components are separated, after which the liquid components are tested to determine the water to oil ratio (for example by measurement of the density thereof).
  • a separator where the gaseous and liquid components are separated, after which the liquid components are tested to determine the water to oil ratio (for example by measurement of the density thereof).
  • Such flow measurement systems are complicated, requiring a great deal of complicated measuring equipment. Also the provision of a suitable separator of reasonable size is not easy.
  • the present invention supplies a simplified phase fraction meter.
  • apparatus for use in a phase fraction meter has a length of pipe defining a fluid passage, a casing defining a chamber surrounding a portion of the pipe and a
  • SUBSTITUTESHEET plurality of perforations extending the length of the chamber and connecting the passage to the chamber, and is characterised in including means for defining, when the pipe is substantially- vertical and has fluid flowing therethrough, interfaces between stratified layers of fluid within the chamber.
  • the means for defining the interfaces might include, for example, one or more floats of appropriate density within the chamber, means for measuring differential pressure between various portions of the chamber, and one or more of acoustic, radiative, electrical or nucleonic instruments disposed within, around or axially along the pipe or chamber.
  • a method for measuring the component fractions in a multi-phase or multi- component flow includes the steps of passing the flow through a substantially vertical pipe, a fluid passage through which is connected by a plurality of perforations to a chamber, and determining the position of interfaces between stratified fluid layers within the chamber.
  • Flow through the pipe can be in either direction. It will be realised that the flow rate through the chamber must be slow, in order for stratification to take place. Only a small fraction of the total flow through the pipe will therefore pass through the chamber. However the percentages of fluids in the chamber at any time will be representative of the total flow.
  • Apparatus for use in the invention includes a length of pipe 10 defining a passage 11.
  • a casing 12 defines a chamber 13 surrounding a portion of the pipe 10.
  • the passage 11 and chamber 13 are connected by a plurality of perforations, such as those shown at lk. which extend along the length of the chamber 13.
  • a pressure transducer ⁇ 6 At an end of the chamber 13 which, in use, will be at the top are a pressure transducer ⁇ 6 and a temperature transducer IT.
  • floats 15a which has a density such that it will settle at an interface between layers of water and oil, and 15b of a density such that it will settle at an interface between oil and gas.
  • the apparatus is connected in a substantially vertical position in the output line from an oil well.
  • Fluid flow from the well will pass through the passage 11. Some of this fluid flow will percolate through the perforations l into the chamber 13 and back through these perforations lk to the passage 11.
  • the rates of percolation there through can be arranged to be such that the components of the flow, namely water, oil and gas will stratify within the chamber 13 as indicated at, respectively, 20, 21 and 22.
  • the floats 15a, 15b will settle at the interfaces between the water and oil, and between oil and gas respectively.
  • the temperature and pressure of the gas will be measured by the instruments l6, IT respectively.
  • Information regarding the position of the floats 15a, 15b and of the temperature and pressure is passed by a means of communications 18 to suitable analysis equipment. It will be realised that as the fractions of the flow through the passage 11 change, so will the rates of flow into and out of the chamber 13 and so will the positions of the interfaces
  • the pressure in layer 22 will be less than in the layer 21, which will be less than that in the layer 20.
  • the pressure in layer 22 will be less than the pressure within the passage 11, and the pressure within the layer 20 will be greater than the pressure within the passage 11. This ensures that there will be continual flow between the passage 11 and chamber 13.
  • apparatus according to the invention can be positioned at any desirable position within the well outlet line, for example close to the well head or close to the output collection point. Fluid flow through the passage 11 may be either upwards or downwards.
  • the apparatus may advantageously be used in conjunction with a mass flow measurement unit measuring total flow through the passage 11. Such a unit need not necessarily be physically close to the apparatus.
  • the pipe 10 may have a cross sectional shape and area which vary along Its length.
  • the sizes and dispositions of the perforations lk may vary along the length of the chamber 13.
  • Performance of the apparatus might be assisted by the presence of baffles in the passage 11, within the chamber 13 or both. It may, in some instances, be advantageous to provide a homogeniser to thoroughly mix gaseous and fluid flow downstream of the chamber 13.
  • a flushing system might be incorporated in the apparatus to clear any deposits away from the perforations lk.
  • Such a system might consist, for example, of a valve positioned in the passage 11 at some position along the chamber 13 so that greatly increased flow is forced through the perforations llj*.
  • SUBSTITUTESHEET radiative, electrical or nucleonic instruments may be disposed within or around the pipe, the chamber or both, or disposed axially along the pipe, chamber or both.
  • Suitable sensors might include, for example, the Texaco Microwave Water Monitor, the Endress and Hauser"Aquasyst” Capacitance meter, the ICI Tracereo or the Sarasota Automation Densitometers, and the Endress and Hauser level sensor.
  • apparatus according to the invention might also be useful for multi-phase or multi-component flows other than those issuing from oil wells and for flows having more than 2 liquid components. When such flows do not contain any gaseous phases there may be no need for instruments such as the pressure sensor 16 and temperature sensor 17.

Landscapes

  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Geology (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Acoustics & Sound (AREA)
  • General Physics & Mathematics (AREA)
  • Measuring Volume Flow (AREA)

Abstract

Un appareil servant à mesurer les diverses fractions dans un système à écoulement polyphasique comprend une chambre (13) définie par un boîtier (12) et par un tuyau (10) définissant un passage (11) auquel la chambre est reliée par l'intermédiaire d'une série de perforations (14). Des moyens (15a, 15b), tels que des flotteurs à l'intérieur de la chambre, sont associés à la chambre (13) et servent à définir les interfaces des couches stratifiées (20, 21, 22) du fluide qui se trouve à l'intérieur de la chambre (13).
PCT/GB1990/001499 1989-10-02 1990-10-01 Appareil mesureur des fractions de phase WO1991005135A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB8922136.0 1989-10-02
GB898922136A GB8922136D0 (en) 1989-10-02 1989-10-02 Phase fraction meter

Publications (1)

Publication Number Publication Date
WO1991005135A1 true WO1991005135A1 (fr) 1991-04-18

Family

ID=10663909

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB1990/001499 WO1991005135A1 (fr) 1989-10-02 1990-10-01 Appareil mesureur des fractions de phase

Country Status (2)

Country Link
GB (1) GB8922136D0 (fr)
WO (1) WO1991005135A1 (fr)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2336209A (en) * 1998-04-09 1999-10-13 S B Services Sensing the presence of liquid of a predetermined specific gravity
US9057252B2 (en) 2011-11-22 2015-06-16 Vetco Gray Inc. Product sampling system within subsea tree
EP2324197A4 (fr) * 2008-08-15 2017-01-18 Well Control Technologies, Inc. Contrôle du niveau de liquide de fond pour puits d hydrocarbures
WO2024030118A1 (fr) * 2022-08-01 2024-02-08 Halliburton Energy Services, Inc. Capteur pour quantifier une teneur de fluide de production en pourcentage

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN109506735B (zh) * 2018-12-31 2020-08-21 杭州路弘科技有限公司 多种不相溶液体的检测方法

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB288725A (en) * 1927-01-14 1928-04-16 Daniel Arthur Quiggin Improvements in apparatus for indicating the rate of flow of a liquid in a mixed flow of liquid and gas; specially applicable to condensed water from steam-heating coils of evaporators for distilling plants, and the like
US4429581A (en) * 1981-05-26 1984-02-07 Baker Cac, Inc. Multiphase flow measurement system
GB2179156A (en) * 1985-08-14 1987-02-25 Ronald Northedge Three-phase flow meter
US4660414A (en) * 1985-09-12 1987-04-28 Texaco Inc. Petroleum stream monitoring means and method

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB288725A (en) * 1927-01-14 1928-04-16 Daniel Arthur Quiggin Improvements in apparatus for indicating the rate of flow of a liquid in a mixed flow of liquid and gas; specially applicable to condensed water from steam-heating coils of evaporators for distilling plants, and the like
US4429581A (en) * 1981-05-26 1984-02-07 Baker Cac, Inc. Multiphase flow measurement system
GB2179156A (en) * 1985-08-14 1987-02-25 Ronald Northedge Three-phase flow meter
US4660414A (en) * 1985-09-12 1987-04-28 Texaco Inc. Petroleum stream monitoring means and method

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2336209A (en) * 1998-04-09 1999-10-13 S B Services Sensing the presence of liquid of a predetermined specific gravity
GB2336210A (en) * 1998-04-09 1999-10-13 S B Services Sensing the presence of liquid of a predetermined specific gravity
EP2324197A4 (fr) * 2008-08-15 2017-01-18 Well Control Technologies, Inc. Contrôle du niveau de liquide de fond pour puits d hydrocarbures
US9057252B2 (en) 2011-11-22 2015-06-16 Vetco Gray Inc. Product sampling system within subsea tree
GB2496976B (en) * 2011-11-22 2016-05-11 Vetco Gray Inc Product sampling system within subsea tree
WO2024030118A1 (fr) * 2022-08-01 2024-02-08 Halliburton Energy Services, Inc. Capteur pour quantifier une teneur de fluide de production en pourcentage

Also Published As

Publication number Publication date
GB8922136D0 (en) 1989-11-15

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