Method and apparatus for measuring multiphase flows

• US 5,591,922 A
• Filed: 05/16/1995
• Issued: 01/07/1997
• Est. Priority Date: 05/27/1994
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Atkinson, Ian, Segeral, Gerard, Long, Peter
• Primary Examiner(s): Chilcot, Richard
• Assistant Examiner(s): Noori, Max H.
• Application Number:
  US08/442,256
• Time in Patent Office: 602 Days
• Field of Search: 73/861.04, 73/861.42, 73/861.66, 73/861.72
• US Class Current: 73/861.04
• CPC Class Codes: G01F 1/36 the pressure or differential pressure being created by the use of flow constriction
• CPC Class Codes: G01F 1/712 using auto-correlation or cross-correlation detection means
• CPC Class Codes: G01F 1/74 Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
• CPC Class Codes: G01F 1/88 with differential-pressure measurement to determine the volume flow

Abstract

A device for measuring flow rate of multiphase fluids such as oilwell effluents, containing liquid hydrocarbons, gas, and water includes first and second sections situated at a distance one from the other in the flow direction, each including a passage provided with structure such as venturis for inducing a change of speed therein, and respective means for measuring the resulting pressure differences, the pressure difference signals obtained in the respective sections being suitable for cross-correlation to produce a signal representative of the total volume flow rate.

Claims

1. A method of measuring flow rate for a multiphase fluid, such as the effluent of an oilwell, which may contain a mixture of liquid hydrocarbons, gas, and water, comprising the steps of:

changing the flow velocity respectively in a first section and in a second section situated at a distance from each other in the flow direction to produce a first and a second pressure difference;

measuring said first and second pressure differences to obtain a first and a second pressure difference signals; and

determining a time lag corresponding to maximum correlation between said first and second pressure difference signals to derive a third signal indicative of the total volume flow rate q.

2. A method according to claim 1, in which said third signal is formed by cross-correlation between the first and second pressure difference signals.

3. A method according to claim 1, in which said measuring step comprises the steps of measuring pressure differences at a plurality of angular positions distributed around the respective sections, and averaging the plurality of measurements thus produced to obtain said first and second signals.

4. A method according to claim 1, in which a further pressure difference resulting from a change in flow velocity is measured in a flow section to obtain a fourth signal that is a function of the total mass flow rate Q and of the density ρ

of the mixture, and a fifth signal is formed representative of said density ρ

.

5. A method according to claim 4, in which said signal representative of the density ρ

is formed by measuring a static pressure difference between two points in the flowing multiphase fluid spaced from each other in the vertical direction.

6. A method according to claim 4, in which said flow section is one of the first and second sections.

7. A method according to claim 6, in which said further pressure difference is measured at positions angularly distinct from the positions at which said first or second pressure differences are measured.

8. A method according to claim 4, in which said flow section is distinct from said first and second sections.

9. A method according to claim 4, in which two possible values for the total mass flow rate Q are formed:

a first value from the fourth signal which is a function both of the total mass flow rate Q and of the density ρ

of the fluid, and also from the fifth signal which is representative of the density ρ

; and

a second value from said fourth signal and from the third signal which is representative of the total volume flow rate q, the first value being appropriate when the gas fraction of the fluid is moderate and the second value being appropriate when the gas fraction is high.

10. A method according to claim 9, in which the density ρ

_l of the liquid fraction of the fluid is determined, with the first and second values of the total flow rate and of the density ρ

_l of the liquid fraction being used to determine respectively first and second values of the gas flow rate and of the liquid flow rate, the corresponding gas content is determined, and one of the first and second values is selected by comparing the resulting gas content with a preestablished limit value.

11. A method according to claim 10, in which the density ρ

_l is determined on the basis of a measurement of the fraction of one of the liquid phases.

12. A method according to claim 1, wherein the flowing multiphase fluid comprises a mixture of fluids flowing from a well.

13. A method according to claim 12, wherein the mixture comprises water, oil and gas.

14. A device for measuring the flow rate of a multiphase fluid, comprising:

first and second sections spaced from each other in the flow direction, each including a passage provided with means for inducing a change of velocity therein; and

first and second means for measuring a pressure difference along respectively said first and second sections and generating first and second pressure difference signals suitable for cross-correlation with each other, said cross-correlation producing a third signal indicative of the total volume flow rate.

15. A device according to claim 14, in which each of said passages includes a venturi.

16. A device according to claim 15, in which each of said first and second measuring means comprises a pressure takeoff located upstream of said venturi and another pressure takeoff located in said venturi.

17. A device according to claim 15, in which each of said first and second measuring means comprises a pressure takeoff located in said venturi and another pressure takeoff located downstream of said venturi.

18. A device according to claim 15, in which each of said first and second measuring means comprises a pressure takeoff located upstream of the venturi and another pressure takeoff located downstream of the venturi.

19. A device according to claim 15, in which each of said sections comprises a plurality of angularly distributed pairs of pressure takeoffs spaced from each other in the flow direction.

20. A device according to claim 14, comprising a third section including a passage provided with means for inducing a change of velocity therein, and third means for measuring a pressure difference along said third section, the signal obtained being a function of the total mass flow rate and of the density ρ

of the mixture, and a fourth section where the flow is upward, provided with means for measuring the static pressure difference between two points spaced from each other in the vertical direction, said pressure difference being indicative of the density ρ

of the mixture.

21. A device according to claim 20, in which said third means is distinct from said first means.

22. A device according to claim 20, in which the third section coincides with said first section.

23. A device according to claim 22, in which said third means includes a plurality of pairs of pressure takeoffs arranged at angularly distributed locations.

24. A device according to claim 14, in which the fluid flows upwards in the first section and downwards in the second section.

25. A device according to claim 14, for measuring the flow rate of the effluent of an oil well containing a mixture of liquid hydrocarbons, gaseous hydrocarbons, and water, the device comprising a gradio-venturi that includes a venturi mounted upstream from a gradiomanometer section of a constant section, and a second venturi placed downstream from the gradio-venturi.

26. A device according to claim 25, in which the second venturi is placed immediately after the gradio-venturi.

27. A device according to claim 25, including a sensor responsible to water fraction, and placed at the level of the gradiomanometer section.

28. A device according to claim 27, wherein the first and second sections and first and second means are located in a pipe which receives fluids flowing from a well.

29. A device according to claim 28, wherein the fluid comprise a mixture of water, oil and gas.

30. A method of determining the production from a well, comprising:

(a) measuring flow rate of multiphase fluids flowing from the well by changing the flow velocity of the flowing multiphase fluid respectively in a first section and in a second section spaced from each other in the flow direction of the fluids;

measuring pressure differences along respectively said first and said second section to obtain a first and a second pressure difference signals; and

comparing said first and second pressure difference signals to derive a third signal indicative of the total volume flow rate q of the flowing multiphase fluid; and

(b) using the measured flow rate to determine the production from the well.