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NO-20260321-A1 - DRILL STRING TORSIONAL DAMPING

NO20260321A1NO 20260321 A1NO20260321 A1NO 20260321A1NO-20260321-A1

Inventors

  • RECKMANN HANNO

Assignees

  • BAKER HUGHES OILFIELD OPERATIONS LLC

Dates

Publication Date
20260311
Application Date
20260311
Priority Date
20230901

Claims (20)

  1. 1. CLAIMS What is claimed is. 1. A system for damping oscillations in a drill string for use in a wellbore comprising: a pipe string; and a damping system comprising, a sleeve selectively rotatable around a portion of the pipe string and selectively engaged to a sidewall of the wellbore, and a coupling unit configured to vary a coupling strength between the pipe string and the sleeve.
  2. 2. The system of Claim 1, wherein the coupling unit comprises one or more magnets and an electrical conduit, and the variation of the coupling strength is caused by varying an electrical current through the electrical conduit.
  3. 3. The system of Claim 1, further comprising one or more ribs on an outer surface of the sleeve that project towards the sidewall of the wellbore.
  4. 4. The system of Claim 1, wherein the damping system comprises a sensor for sensing a vibration parameter indicative of a vibration of the system in the wellbore and wherein the coupling unit varies the coupling strength in response to the sensed vibration parameter.
  5. 5. The system of Claim 4, further comprising a controller in communication with the sensor, the controller configured to initiate the coupling unit to vary the coupling strength based on the sensed vibration parameter.
  6. 6. The system of Claim 4, wherein the controller is configured to split the sensed vibration parameter in a first and second vibration portion having a frequency from a first and second frequency range, respectively.
  7. 7. The system of Claim 1, wherein the coupling unit comprises a coupling selected from the group consisting of a brake type coupling and a magnetic coupling.
  8. 8. The system of Claim 1, wherein the coupling unit comprises a magnetorheological fluid, wherein the coupling strength is varied by energizing the magnetorheological fluid.
  9. 9. The system of Claim 6, wherein at least one of the first and second frequency range is a discrete frequency value.
  10. 10. The system of Claim 9, wherein at least one of the first and second frequency range is a static frequency component.
  11. 11. A method for damping oscillations in a drill string operated in a wellbore, the method comprising: lowering at least a portion of a pipe string into the wellbore, the pipe string comprising a damping system including a sleeve and a coupling unit; engaging the sleeve to a sidewall of the wellbore; varying, by the coupling unit, a coupling strength between the pipe string and the sleeve.
  12. 12. The method of Claim 11, wherein the coupling unit comprises one or more magnets and an electrical conduit, and the variation of the coupling strength is caused by varying an electrical current through the electrical conduit.
  13. 13. The method of Claim 11 , further comprising projecting one or more ribs on an outer surface of the sleeve towards the sidewall of the wellbore.
  14. 14. The method of Claim 11, further comprising sensing, with a sensor in the damping system, a vibration parameter indicative of a vibration of the drill string in the wellbore and varying the coupling strength in response to the sensed vibration parameter.
  15. 15. The method of Claim 14, wherein the variation of the coupling strength by the coupling unit is initiated by a controller in communication with the sensor based on the sensed vibration parameter.
  16. 16. The method of Claim 14, further comprising splitting, by the controller, the sensed vibration parameter and a first and second vibration portion having a frequency from a first and second frequency range, respectively.
  17. 17. The method of Claim 11, wherein the coupling unit is varying the coupling strength by at least one of a hydraulic coupling, a magnetic coupling, or an electromagnetic coupling.
  18. 18. The method of Claim 11 , wherein the coupling unit comprises a magnetorheological fluid, and wherein the variation of the coupling strength comprises energizing the magnetorheological fluid.
  19. 19. The method of Claim 16, wherein at least one of the first and second frequency range is a discrete frequency value.
  20. 20. The method of Claim 19, wherein at least one of the first and second frequency range is a static frequency component.

Description

[0001] PCT PATENT APPLICATION [0004] DRILL STRING TORSIONAL DAMPING [0006] Inventor: Hanno RECKMANN [0008] This application claims priority to and the benefit of co-pending U.S. Provisional Application Serial No. 63/580,086, filed September 1, 2023, the entirety of which is incorporated by reference herein in its entirety and for all purposes. [0011] BACKGROUND OF THE INVENTION [0013] 1. Field of Invention [0015] The present disclosure relates to a wellbore drilling system that includes a drill string with an outer sleeve configured to dampen vibrations in the drill string. [0017] 2. Description of Prior Art [0019] Drilling systems employed for excavating hydrocarbon producing wellbores in a subterranean formation, and which typically include a drill string made up of a pipe string, a drill bit, a bottom hole assembly (“BHA”) containing tools for measurements and directional steering between the drill bit and the pipe string, and a collar connecting the drill bit to the pipe string. The drill string is generally made up of joints of drill pipes connected in series by engaging threads on their opposing ends. Usually, the drill string is rotated by a top drive or rotary table provided in a drilling rig on surface while drilling mud is circulated within the drill string to remove cuttings formed by rotating the drill bit in the subterranean formation. [0021] [0004] Reactive forces from the drill bit rotating against the subterranean formation, such as rock formations can generate vibrations in the BHA and the drill string, which are generally most pronounced and damaging close to the drill bit in the BHA. Depending on the forces and physical characteristics of the drill string and the subterranean formation, the vibrations are in directions that are radial, torsional, and combinations, which can include high-frequency torsional oscillations (“HFTO”). Recent advancements in drilling technology have increased both rates of penetration through the subterranean formation and force on the drill bit (also commonly referred to as “weight on bit”), and in turn increased magnitudes of vibrational displacement in the BHA and drill strings, thereby increasing a probability of damaging the BHA and drill string. One technique for damping vibrations in a drill string include adding a free rotating inertia mass to a portion of the drill string. One drawback to this technique is the limited space available within a bottom hole assembly. [0022] SUMMARY OF THE INVENTION [0024] Disclosed herein is an example of a system for damping oscillations in a drill string for use in a wellbore that includes a pipe string and a damping system, where the damping system is made up of a sleeve selectively rotatable around a portion of the pipe string and selectively engaged to a sidewall of the wellbore and a coupling unit configured to vary a coupling strength between the pipe string and the sleeve, hi an embodiment, the coupling unit includes one or more magnets and an electrical conduit, and the variation of the coupling strength is caused by varying an electrical current through the electrical conduit. The system further optionally includes one or more ribs on an outer surface of the sleeve that project towards the sidewall of the wellbore. The damping system optionally includes a sensor for sensing a vibration parameter indicative of a vibration of the system in the wellbore and where the coupling unit varies the coupling strength in response to the sensed vibration parameter, in an alternative, a controller is included in communication with the sensor, the controller configured to initiate the coupling unit to vary the coupling strength based on the sensed vibration parameter, and optionally, the controller is configured to split the sensed vibration parameter in a first and second vibration portion having a frequency from a first and second frequency range, respectively. In examples, the coupling unit includes a coupling that is a brake type coupling or a magnetic coupling. In an embodiment, the coupling unit includes a magnetorheological fluid, wherein the coupling strength is varied by energizing the magnetorheological fluid. Examples of the first and second frequency range include a discrete frequency value. In an alternative, the at least one of the first and second frequency range is a static frequency component. [0026] [0006] Also disclosed is an example method for damping oscillations in a drill string operated in a wellbore, and which includes lowering into the wellbore at least a portion of a pipe string made up of a damping system including a sleeve and a coupling unit. The example method further includes engaging the sleeve to a sidewall of the wellbore, and varying, by the coupling unit, a coupling strength between the pipe string and the sleeve. The coupling unit optionally includes one or more magnets and an electrical conduit, and the variation of the coupling strength is caused by