Wellbore evaluation system and method

• US 20060271299A1
• Filed: 05/09/2006
• Published: 11/30/2006
• Est. Priority Date: 05/25/2004
• Status: Active Grant

• Current Assignee: Robbins & Myers Energy Systems LP (NOV, Inc.)
• Original Assignee: Robbins & Myers Energy Systems LP (NOV, Inc.)
• Inventors: Ward, Simon J., Rogers, John P.
• Granted Patent: US 7,346,455 B2
• Time in Patent Office: Days
• US Class Current: 702/6
• CPC Class Codes: E21B 47/008 Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
• CPC Class Codes: E21B 47/009 Monitoring of walking-beam pump systems
• CPC Class Codes: E21B 47/022 of the borehole, e.g. using geomagnetism
• CPC Class Codes: E21B 47/085 using radiant means, e.g. acoustic, radioactive or electromagnetic

Abstract

A wellbore evaluation system evaluates mechanical wear and corrosion to components of a well system including a production tubing string positionable in a well and a sucker rod string movable within the production tubing string. A deviation sensor determines a deviation profile of the production tubing string in the well, and a rod sensor senses and measures wear and corrosion to the sucker rod string as it is removed from the well to determine a rod profile. A data acquisition computer is in communication with the sensors for computing and comparing the deviation profile and the rod profile as a function of depth in the well. A 3-dimensional image of wellbores, with isogram mapping, may be generated and examined over the internet.

Claims

1. A wellbore evaluation system for evaluating the condition of components of a well system, the well system including at least one of a production tubing string positioned in a well and a sucker rod string movable within the production tubing string, the system comprising:

a deviation sensor package movable within the production tubing string while in the well to measure deviation and inclination of the wellbore as a function of depth to generate a deviation profile;

a string sensor package for sensing wear or corrosion of at least one of the tubing string and the rod string as it is removed from the well to generate a string profile as a function of depth; and

a computer in communication with the deviation sensor package and the string sensor package for comparing the deviation profile and the string profile as a function of depth in the well.

2. A system as defined in claim 1, wherein the computer displays the deviation profile in substantially real time, and also displays the string profile in substantially real time.

3. A system as defined in claim 1, wherein the computer displays the string profile and the deviation profile in three dimensions.

4. A system as defined in claim 1, wherein the computer transmits the deviation profile and the string profile to another internet compatible computer.

5. A system as defined in claim 1, further comprising:

one or more standoff sensors at the well site to measure a standoff between a sensor in the string sensor package and an outer surface of the string.

6. A system as defined in claim 1, further comprising:

a bar code marking device for marking segments of the production tubing string or the rod string when pulled from the well;

a bar code reader for reading the bar code markings on segments of the production tubing string when inserted into the well; and

the computer tracking segments of the production tubing string and the rod string.

7. A system as defined in claim 6, wherein the readings are RFID tags attached to the production tubing string and/or the sucker rod string.

8. A system as defined in claim 1, wherein the deviation sensor package comprises:

three pairs of gyroscopes and three pairs of accelerometers, each pair being positioned orthogonally to each other to measure deviation from vertical and deviation as to azimuth.

9. A system as defined in claim 8, wherein each of the gyroscopes and the accelerometer are a single chip MEMS device.

10. A system as defined in claim 1, wherein the string sensor package comprises:

one or more of a magnetic flux sensor coil, a Hall effect device, an LVDT, a laser micrometer and a laser triangulation sensor.

11. A system as defined in claim 1, wherein the string sensor package comprises:

a tubing sensor package for detecting wear to the tubing string as it is pulled from the well to generate a tubing string profile; and

a rod string sensor package for detecting wear to the rod string as it is pulled from the well to generate a rod string profile.

12. A system as defined in claim 11, wherein the computer simultaneously displays the deviation profile, the rod string profile, and the tubing string profile.

13. A method for evaluating wear to components of a well system, the well system including at least one of a production tubing string positioned in a well and a sucker rod string movable within the production tubing string, the method comprising:

moving a deviation sensor package within the production tubing string while in the well to generate a deviation profile as a function of depth;

sensing wear to at least one of the tubing string and the sucker rod string as a function of depth as the string is removed from the well to determine a string profile; and

comparing of the deviation profile and string profile as a function of depth in the well.

14. A method as defined in claim 13, wherein the computer displays the deviation profile in substantially real time and the string profile in substantially real time.

15. A method as defined in claim 13, wherein the computer displays the string profile and the deviation profile in three dimensions.

16. A method as defined in claim 13, wherein the computer transmits the deviation profile and the string profile to another internet compatible computer.

17. A method as defined in claim 13, further comprising:

one or more standoff sensors at the well site to measure a standoff between a standoff sensor and an outer surface of the string.

18. A method as defined in claim 13, further comprising:

a bar code marking device for marking segments of the production tubing string or the rod string when pulled from the well;

a bar code reader for reading the bar code markings on the segments when inserted into the well; and

the computer tracking the segments of the production tubing string and the rod string.

19. A method as defined in claim 13, wherein the readings are RFID tags attached to the production tubing string and/or the sucker rod string.

20. A method as defined in claim 13, wherein the sensor package comprises:

one or more of a magnetic flux sensor coil, a Hall effect device, an LVDT, a laser micrometer and a laser triangulation sensor.

21. A method as defined in claim 13, wherein the computer displays a three dimensional downhole profile from multiple wells.

22. A method as defined in claim 13, further comprising:

sensing wear to the production tubing string as it is removed from the well to determine a tubing wear profile; and

sensing wear to the sucker rod string as it is removed from the well to determine a sucker rod wear profile.

23. A system for measuring the deviation of a well bore in three axes, comprising:

three pairs of orthogonally positioned MEMS Coriolis-effect gyroscopes positioned on a tool to determine a direction;

three pairs of MEMS accelerometers positioned on the tool to determine indication from vertical;

inserting the tool in a production tubing string; and

a computer in communication with the gyroscopes and the accelerometer for computing the well deviation.

24. A method as defined in claim 23, wherein the tool passes through a tubing string in the well while the gyroscopes and accelerometers take measurements.

25. A method as defined in claim 23, wherein a GPS device is used to initially determine the tool location.

26. A method as defined in claim 23, wherein the measured well deviation is used to estimate side loads and predict tubing string wear by engagement with the sucker rod.

27. A wellbore evaluation system for evaluating the condition of components of a well system, the well system including at least one of a production tubing string positioned in a well and a sucker rod string movable within the production tubing string, the system comprising:

a string sensor package comprising 24 or more circumferentially oriented sensors for sensing wear or corrosion of at least one of the tubing string and the rod string as it is removed from the well to generate a string profile as a function of depth; and

a computer in communication with the string sensor package for generating the string profile as a function of depth in the well and circumferential position of a sensor.

28. A system as defined in claim 27, wherein the computer displays the string profile in substantially real time.

29. A system as defined in claim 27, further comprising:

one or more standoff sensors at the well site to measure a standoff between a sensor in string sensor package and an outer surface of the string.

30. A system as defined in claim 27, wherein the string sensor package comprises:

one or more of a magnetic flux sensor coil, a Hall effect device, an LVDT, a laser micrometer and a laser triangulation sensor.

31. A system as defined in claim 28, wherein:

the string sensor package includes one or more of a magnetic flux coil sensor, a Hall effect sensor, an LVDT sensor, a laser micrometer sensor, and a laser triangulation sensor; and

the computer processes multiple signals from a plurality of said sensors as a function of both depth of the string in the well and circumferential position of a sensor about the string; and

the computer displays, in substantially real time as the string is pulled from the well, a representation of the cross-section of the string and a representation of an outer diameter of the string, and a representation of wall thickness of the string, based on axial depth of the string being tested and a circumferential position of specific sensors, such that individual lengths of a string may be classified as to fitness for purpose.