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A method and apparatus for determining the location of stuck pipe are provided. In one embodiment, the method includes the step of attaching a free point logging tool to a working line such as a slickline or wireline. The free point logging tool has a freepoint sensor and, optionally, an acoustic se

A method and apparatus for determining the location of stuck pipe are provided. In one embodiment, the method includes the step of attaching a free point logging tool to a working line such as a slickline or wireline. The free point logging tool has a freepoint sensor and, optionally, an acoustic sensor. The freepoint sensor acquires magnetic permeability data in a string of pipe, while the acoustic sensor acquires acoustic data in the pipe. Two sets of data for each sensor are acquired--one in which the pipe under investigation is unstressed, and one in which the pipe is stressed. The first set and second sets of magnetic permeability data are compared to determine the stuck point location for the pipe. The first and second sets of acoustic data are compared to determine the nature in which the pipe is stuck.

대표청구항 ▼

What is claimed is: 1. A method for detecting a condition of an oil field tubular, comprising: conveying a detection tool along an interior of the tubular on a slickline; transmitting a waveform from the detection tool to a wall of the tubular, the waveform interacting with the wall; receiving an i

What is claimed is: 1. A method for detecting a condition of an oil field tubular, comprising: conveying a detection tool along an interior of the tubular on a slickline; transmitting a waveform from the detection tool to a wall of the tubular, the waveform interacting with the wall; receiving an interacted waveform from the wall of the tubular; and communicating the condition of the tubular based upon the received interacted waveform to a user, wherein the condition is a stuck point or a free point. 2. The method of claim 1, further including communicating data regarding the condition to a surface of a wellbore. 3. The method of claim 1, further including communicating data regarding the condition to a memory module in the detection tool. 4. The method of claim 1, further including communicating data regarding the condition through a telemetry module in the detection tool to a receiver proximate a surface of a wellbore. 5. The method of claim 1, wherein the detection tool includes a transmitter for transmitting the waveform and a receiver for receiving the interacted waveform. 6. The method of claim 1, wherein a wireline conveys the detection tool along the interior of the tubular. 7. The method of claim 1, wherein a coil tubing conveys the detection tool along the interior of the tubular. 8. The method of claim 1, wherein the oilfield tubular is a drill pipe. 9. The method of claim 1, wherein the oilfield tubular is a tubing. 10. The method of claim 1, wherein the oilfield tubular is a casing. 11. The method of claim 1, wherein the oilfield tubular is a pipeline. 12. The method of claim 1, further including storing data representative of a portion of the interacted waveform. 13. The method of claim 1, wherein the waveform is an electromagnetic waveform. 14. The method of claim 1, further comprising using the detection tool for receiving the interacted waveform. 15. The method of claim 1, wherein the waveform is an acoustic waveform. 16. The method of claim 1, wherein the waveform is a magnetic waveform. 17. The method of claim 1, wherein the waveform is an electric waveform. 18. An apparatus for detecting a condition of an oilfield tubular, comprising a detection tool having a body; a waveform generating transmission portion; a waveform receiving portion; and a user interface for communicating detection of the condition to the user, wherein the condition is a stuck point of the oil field tubular. 19. The apparatus of claim 18, wherein at least one of the waveform generating transmission portion and the waveform receiving portion is a pickup or lens. 20. The apparatus of claim 18, further including a cable head capable of connecting to a conveyance member. 21. The apparatus of claim 20, wherein the conveyance member is a slickline. 22. The apparatus of claim 21, further including a memory module coupled to the detection tool for storing data. 23. The apparatus of claim 18, wherein the oilfield tubular is a drill pipe, a tubing, a casing or a pipeline. 24. The apparatus of claim 18, further including a self contained power source for energizing the detection tool. 25. The apparatus of claim 18, wherein the waveform generating transmission portion transmits a waveform to the tubular. 26. The apparatus of claim 25, wherein the receiving portion receives an interacted waveform from the tubular. 27. A method for conducting an operation in an oil field tubular, comprising conveying a detection tool including a downhole memory into a wellbore on an electrically non-conductive mechanical connection member and along an interior of the tubular; detecting a condition of the tubular by transmitting a waveform from the detection tool to a wall of the tubular and receiving an interacted waveform from the wall of the tubular, wherein the condition of the tubular is a stuckpoint or a freepoint; and storing the detected condition in the downhole memory. 28. The method of claim 27, further including inducing a stress in the tubular. 29. The method of claim 28, further including transmitting a second waveform from the detection tool to a wall of the stressed tubular and receiving a second interacted waveform from the wall of the tubular. 30. The method of claim 29, further including comparing the interacted waveform. 31. The method of claim 27, wherein the electrically non-conductive mechanical connection member is a slickline. 32. The method of claim 27, wherein the electrically non-conductive mechanical connection member is a coiled tubing. 33. The method of claim 27, further including communicating data regarding the condition to the surface of the wellbore. 34. The method of claim 27, further including communicating data regarding the condition through a telemetry module of the detection tool to a receiver proximate a surface of the wellbore. 35. The method of claim 27, wherein the detection tool includes a transmitter for transmitting the waveform and a receiver for receiving the interacted waveform. 36. The method of claim 27, wherein the oilfield tubular is at least one of a drill pipe, a tubing, a casing and a pipeline. 37. The method of claim 27, further including powering the detection tool with a power module. 38. The method of claim 27, further including memorizing data from the detection tool. 39. The method of claim 27, wherein detecting the condition comprises detecting a plurality of conditions over a length of the tubular. 40. The method of claim 39, further including memorizing the plurality of conditions. 41. An apparatus for conducting an operation in an oil field tubular, comprising: an electrically non-conductive mechanical connection member configured to convey a detection tool, the detection tool comprising: a power module; a waveform transmitter/receiver including a waveform generating portion and a waveform receiving portion wherein the waveform generating portion is configured to send a waveform to interact with the oil field tubular and the waveform receiving portion is configured to receive an interacted waveform from the tubular; a data processing module; and a memory module, configured to store data received by the waveform transmitter/receiver, wherein the data comprises at least one internal characteristic of a wall of the oil field tubular. 42. The apparatus of claim 41, wherein the data received by the waveform transmitter/receiver is a condition of a tubular in a borehole. 43. The apparatus of claim 42, wherein the condition is a stress in the tubular. 44. A method for detecting a condition of an oil field tubular, comprising: conveying a detection tool along an interior of the tubular on a slickline; transmitting a waveform from the detection tool to a wall of the tubular, the waveform interacting with the wall; receiving an interacted waveform from the wall of the tubular; and communicating the condition of the tubular based upon the received interacted waveform to a user, wherein the condition is a tubular thickness. 45. A method for detecting a condition of an oil field tubular, comprising: conveying a detection tool along an interior of the tubular on a slick line; inducing a stress in the tubular; transmitting a waveform from the detection tool to a wall of the tubular, the waveform interacting with the wall; receiving an interacted waveform from the wall of the tubular; and communicating the condition of the tubular based upon the received interacted waveform to a user. 46. The method of claim 45, wherein the stress comprises a torsional stress. 47. The method of claim 45, wherein the stress comprises a tensile stress. 48. The method of claim 47, further including transmitting a second waveform from the detection tool to a wall of the stressed tubular and receiving a second interacted waveform from the wall of the tubular. 49. The method of claim 48, further including comparing the interacted waveform and the second interacted waveform.