Method and system for measurement of fluid flow in a drilling rig return line

• US 5,063,776 A
• Filed: 12/14/1989
• Issued: 11/12/1991
• Est. Priority Date: 12/14/1989
• Status: Expired due to Fees

• Current Assignee: Anadrill Incorporated (Schlumberger NV)
• Original Assignee: Anadrill Incorporated (Schlumberger NV)
• Inventors: Orban, Jacques, Zanker, Klaus J.
• Primary Examiner(s): NOT, DEFINED
• Assistant Examiner(s): Miller, Craig
• Application Number:
  US07/450,807
• Time in Patent Office: 698 Days
• Field of Search: 73/3, 73/155, 73/215, 73/151, 73/290 V, 73/861, 73/53, 364/422
• US Class Current: 73/152.21
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• CPC Class Codes: G01F 1/002 wherein the flow is in an open channel
• CPC Class Codes: G01F 23/2962 Measuring transit time of reflected waves

Abstract

Improved methods and systems are provided for determining a volumetric flow rate of mud in a return line without the aid of a velocity probe. A mud level sensor is located in a return line chimney preferably in close proximity to the bell nipple. The sensor senses the height of the mud flowing in the return line. Where an ultraonsic transceiver is used as the sensor, temperature sensors in the chimney and return line determine a temperature gradient in the return line which provides a speed of sound correction as does a target at a known distance from the transceiver. A computer receives the uncorrected mud height and the speed of sound information, and determines the flow-out volume of the mud. Flow-out volume is related to the mud height, the geometry of the return line, and mud parameters. In a more complete system, the computer calibrates the determined flow-out volume with the flow-in volume, and provides a correction factor which is used to provide a corrected flow-out determination. The computer also monitors delta flow (flow-out minus flow-in), and based on the rate of change of delta flow determines when an undesirable condition such as a kick or fluid loss occurs. Where the system is to be used on rig which is subject to movement (e.g. a floating rig), an angle sensor is employed to help determine instantaneous flow-out, and the flow-out determinations are averaged over the movement cycle of the rig as determined by heave position sensors available on the rig.

Claims

1. A system for obtaining an indication of volumetric flow of a drilling mud exiting a well bore through an annulus between a drill pipe and the well bore and up to a bell nipple and out to a drilling rig return line connected to said bell nipple at an angle such that said drilling mud partially fills said return line and is in supercritical flow in said return line, said return line having a known physical configuration, said system comprising:

a) a non-intrusive mud level sensor means located in or in proximity to said return line for sensing the height of the mud flowing in the return line without affecting mud flow and for providing signals indicative thereof; and

b) means responsive to said level sensor signals, and in conjunction with return line configuration, for providing an indication of the flow-out volume of the mud from said well bore.

2. A system according to claim 1, further comprising:

c) means for detecting an indication of flow-in volume to said well bore; and

d) calibration means for calibrating the flow-out volume indication with the flow-in volume indication to provide a correction indication, and for using said correction indication and said flow-out volume to provide a corrected flow-out volume determination.

3. A system according to claim 1, further comprising:

c) means for obtaining an indication of flow-in volume to said well bore; and

d) means responsive to said indications of flow-in and flow-out volumes for determining an undesirable condition in said well bore.

4. A system according to claim 2, further comprising:

e) means responsive to said calibration means for determining an undesirable condition in said well bore.

5. A system according to claim 1, further comprising

c) angle sensing means for sensing the angle of said return line and providing indications thereof to said means (b) which is further responsive thereto, wherein

said return line configuration data comprises return line angle as determined by said angle sensing means, and return line shape.

6. A system according to claim 4, wherein:

said return line configuration data comprises return line angle and return line shape.

7. A system according to claim 1, further comprising:

c) a chimney fixed to said return line, said acoustic level sensor means being supported by said chimney.

8. A system according to claim 7, wherein:

said level sensor means is an acoustic level sensor, said system further comprising

d) correction sensor means for determining at least one ambient condition in said return line, and for providing signals indicative thereof to said means responsive to level sensor signals.

9. A system according to claim 8, wherein:

said acoustic level sensor means is an ultrasonic pulse echo transceiver; and

said correction sensor means includes a plurality of temperature sensors located at different heights relative to said the surface of said mud flowing in said return line.

10. A system according to claim 9, wherein:

said plurality of temperature sensors comprises a first temperature sensor located in relative close proximity to and above said mud surface, a second temperature sensor located substantially at the junction of said return line and said chimney, and a third temperature sensor located in said chimney in relative close proximity to said transceiver.

11. A system according to claim 10, wherein:

said correction sensor further includes a target supported by said chimney or said return line and mounted above said mud surface and at a determinable distance from said transceiver for reflecting a portion of the acoustic energy transmitted by said transceiver back to said transceiver.

12. A system according to claim 11, wherein:

said target is mounted on a pole which is adjustably supported by said chimney.

13. A system according to claim 4, further comprising:

f) a chimney fixed to said return line,

wherein said level sensor means is an ultrasonic pulse echo transceiver supported by said chimney,

said correction sensor means includes a plurality of temperature sensors located at different heights relative to said the surface of said mud flowing in said return line, and a target supported by said chimney or said return line and mounted above said mud surface and at a determinable distance from said transceiver for reflecting a portion of the acoustic energy transmitted by said transceiver back to said transceiver.

14. A system according to claim 3, wherein:

said level sensor means is located within ten feet of said bell nipple.

15. A system according to claim 4, wherein:

said level sensor means is located within ten feet of said bell nipple.

16. A system according to claim 7, wherein:

said level sensor means is located within ten feet of said bell nipple.

17. A system according to claim 11, wherein:

said level sensor means is located within ten feet of said bell nipple.

18. A system according to claim 5, wherein:

said means responsive to said level sensor is further responsive to a signal indicative of a movement cycle of said rig, and averages said flow-out volume indications over said movement cycle.

19. A system according to claim 18, further comprising:

d) means for obtaining an indication of flow-in volume to said well bore;

e) calibration means for calibrating said averaged flow-out volume indications with said flow-in volume indications; and

f) means responsive to said calibration means for determining an undesirable condition in said well bore.

20. A system according to claim 19, further comprising:

g) a chimney fixed to said return line; and

h) correction sensor means for determining at least one ambient condition in said return line, and for providing signals indicative thereof to said means responsive to level sensor signals,

wherein said level sensor means is an ultrasonic pulse echo transceiver supported by said chimney, and

said correction sensor means includes a plurality of temperature sensors located at different heights relative to said the surface of said mud flowing in said return line.

21. A system according to claim 20, wherein:

said plurality of temperature sensors comprises a first temperature sensor located in relative close proximity to and above said mud surface, a second temperature sensor located substantially at the junction of said return line and said chimney, and a third temperature sensor located in said chimney in relative close proximity to said transceiver, and

said correction sensor further includes a target supported by said chimney or said return line and mounted above said mud surface and at a determinable distance from said transceiver for reflecting a portion of the acoustic energy transmitted by said transceiver back to said transceiver.

22. A system according to claim 12, wherein:

said means (b) is responsive to the location of said target, and further provides an indication of the amount of methane gas in said return line.

23. A method for determining, without obtaining a direct indication of mud velocity from a velocity measurement probe, an indication of the volumetric flow rate of a drilling mud exiting a well bore through an annulus between a drill pipe and the well bore and up to a bell nipple and out to a drilling rig return line said return line having a known physical configuration and being connected to said bell nipple, said drilling mud partially filling said return line, said method comprising:

a) sensing the height of the mud flowing in the return line at a location in said return line where said mud is in supercritical flow, and providing signals indicative thereof;

b) determining flow-out volume of the mud as a function of at least said mud height signals, and the physical configuration of said return line.

24. A method according to claim 23, further comprising:

c) sensing at least one ambient condition in said return line so as to provide speed of sound information in said return line, and providing signals indicative thereof, wherein said step of determining flow-out volume determines flow-out volume as a further function of said at least one ambient condition.

25. A method according to claim 23, further comprising:

c) obtaining an indication of flow-in volume into said well bore;

d) calibrating indications of the determined flow-out volume with indications of the flow-in volume to provide a calibration factor, the product of said flow-out volume and said calibration factor providing a corrected flow-out volume.

26. A method according to claim 25, further comprising:

e) monitoring the differences between said corrected flow-out volume and said flow-in volume over time; and

f) identifying an undesirable condition in said well bore by monitoring the rate of change of said monitored differences.

27. A method according to claim 24, further comprising:

d) obtaining an indication of flow-in volume into said well bore;

e) calibrating indications of the determined flow-out volume with indications of the flow-in volume to provide a calibration factor, the product of said flow-out volume and said calibration factor providing a corrected flow-out volume.

28. A method according to claim 27, further comprising:

f) monitoring the differences between said corrected flow-out volume and said flow-in volume over time; and

g) identifying an undesirable condition in said well bore by monitoring the rate of change of said monitored differences.

29. A method according to claim 23, further comprising:

c) sensing the angle of said return line, wherein said configuration of said return line includes said angle;

d) sensing the movement of the rig and determining a movement cycle therefrom; and

e) averaging flow-out volume indications over said movement cycle.

30. A method according to claim 29, further comprising:

f) obtaining an indication of a flow-in volume to said well bore;

g) calibrating the averaged flow-out volume with the flow-in volume to provide a calibration factor, the product of said average flow-out volume and said calibration factor providing a corrected average flow-out volume.

31. A method according to claim 30, further comprising:

h) monitoring the differences between said corrected flow-out volume and said flow-in volume over time; and

i) identifying an undesirable condition in said well bore by monitoring the rate of change of said monitored differences.

32. A method according to claim 31, further comprising:

j) sensing at least one ambient condition in said return line so as to provide speed of sound information in said return line, and providing signals indicative thereof, wherein said step of determining flow-out volume determines flow-out volume as a further function of said at least one ambient condition.

33. A method according to claim 24, further comprising:

d) calculating an indication of the amount of methane gas in said return line, wherein said at least one ambient condition in said return line comprises a temperature profile in said return line.