Downhole state-machine-based monitoring of vibration

1. A vibration monitoring method that comprises:

processing sensor information downhole to detect one or more vibration modes;

updating a current state of a vibration mode state machine downhole based at least on part on any of the one or more detected vibration modes, wherein a residence time, severity level, and path information are associated with the current state of the downhole vibration mode state machine, the residence time is a counter or indication of the time the current state has been active;

communicating a representation of the current state of the downhole vibration mode state machine to an uphole module with employment of mud pulse telemetry;

reconstructing, by the uphole module, the current state of the downhole vibration mode state machine from the representation of the current state of the downhole vibration mode state machine to determine a primary vibration mode and severity thereof;

modifying at least one drilling parameter of a drill string situated downhole based on the reconstructed current state of the downhole vibration mode state machine by the uphole module, wherein:

the processing occurs downhole in a downhole tool controller and employs a naïve-Bayes classification to detect a presence or absence of each of the one or more vibration modes independent of any others of the one or more vibration modes if there are any other vibration modes of the one or more vibration modes, and

each of the classification of vibration modes of the naïve-Bayes classification are pre-programmed before employing the naïve-Bayes classification.

2. The method of claim 1 , wherein the uphole module tracks a history of the current state of the downhole vibration mode state machine and analyzes the history.

3. The method of claim 2 , wherein:

the representation of the current state of the downhole vibration mode state machine has an associated first indicia of the primary vibration mode corresponding to when the current state of the downhole vibration mode state machine became active, and

the representation of the current state of the downhole vibration mode state machine has an associated second indicia of the primary vibration mode corresponding to a time when an immediately preceding state of the downhole vibration mode state machine occurred.

4. The method of claim 3 , wherein the representation of the current state of the downhole vibration mode state machine designates both the primary vibration mode and a secondary vibration mode.

5. The method of claim 1 , wherein the representation of the current state of the downhole vibration mode state machine includes a severity for each of multiple vibration modes of the one or more vibration modes.

6. The method of claim 1 , wherein the sensor information includes multi-axial acceleration sampled at 10 Hz or higher.

7. The method of claim 6 , wherein the processing includes deriving a multi-axial jerk signal from the multi-axial acceleration.

8. The method of claim 1 , wherein the processing includes detecting the one or more vibration modes from a set that includes stick-slip, bit bounce, bit whirl, bottomhole assembly (BHA) whirl, lateral shocks, torsional resonance, parametric resonance, and bit chatter.

9. The method of claim 8 , wherein the vibration mode state machine includes at least one state for each of the vibration modes in the set.

10. The method of claim 1 , further comprising tracking an amount of time spent in each state of the vibration mode state machine and communicating the amounts to the uphole module.

11. The vibration monitoring method of claim 1 , wherein:

the sensor information includes multi-axial acceleration signals, and

the processing includes deriving a multi-axial jerk signal from the multi-axial acceleration signals and using the naïve Bayes classification to detect the presence or absence of the one or more vibration modes independent of other vibration modes.

12. A drilling system that comprises:

a drill string having a bit for extending a borehole;

a rig that conveys the drill string into the borehole using at least one controllable drilling parameter;

one or more downhole sensors coupled to the drill string and providing vibration-related signals;

a downhole processor in a downhole tool controller that:

operates on axial acceleration signals of the vibration-related signals,

employs naïve-Bayes classification to detect one or more vibration modes, and

responsively updates a current state of a vibration mode state machine, wherein:

a residence time, severity level, and path information are associated with the current state of the downhole vibration mode state machine, the residence time is a counter or indication of the time the current state has been active,

the downhole processor operates on the axial acceleration signals for the naïve-Bayes classification,

the naïve Bayes classification detects a presence or absence of each of the vibration modes independent of any others of the one or more vibration modes if there are any, and

each of the classification of vibration modes of the naïve-Bayes classification are pre-programmed before employing the naïve-Bayes classification;

an uphole module coupled to the rig or other deployment device, wherein the uphole module:

receives, with employment of mud pulse telemetry, a representation of the current state of the downhole vibration mode state machine from the downhole processor, and

reconstructs the current state of the downhole vibration mode state machine from the representations of the current state of the downhole vibration mode state machine to determine at least a primary vibration mode and severity, wherein the at least one controllable drilling parameter is modified based on the reconstructed current state of the downhole vibration mode state machine by the uphole module.

13. The system of claim 12 , wherein the at least one controllable drilling parameter comprises: a weight on bit, a bit rotation rate, a drill string rotation rate, a torque, a rate of penetration, a flow rate, or a differential pressure.

14. The system of claim 12 , wherein:

the uphole module tracks a history of the current state of the downhole vibration mode state machine as part of determining the primary vibration mode from the reconstructed current state of the downhole vibration mode state machine,

the representation of the current state of the downhole vibration mode state machine has an associated first indicia of the primary vibration mode corresponding to when the current state of the downhole vibration mode state machine became active, and

the representation of the current state of the downhole vibration mode state machine has an associated second indicia of the primary vibration mode corresponding to a time when an immediately preceding state of the downhole vibration mode state machine occurred.

15. The system of claim 12 , wherein the representation of the current state of the downhole vibration mode state machine includes a severity for each of multiple vibration modes of the one or more vibration modes.

16. The system of claim 12 , wherein the vibration-related signals comprise multi-axial acceleration signals.

17. The system of claim 16 , wherein as part of the operating on the axial acceleration signal of the vibration-related signals, the downhole processor derives a multi-axial jerk signal from the multi-axial acceleration signals.

18. The system of claim 12 , wherein the vibration mode state machine includes at least one state for each of the following vibration modes: stick-slip, bit bounce, bit whirl, bottomhole assembly (BHA) whirl, lateral shocks, torsional resonance, parametric resonance, and bit chatter.

19. The drilling system of claim 12 , wherein:

the axial acceleration signals include multi-axial acceleration signals, and

the downhole processor is configured to derive a multi-axial jerk signal from the multi-axial acceleration signals and configured to use the naïve Bayes classification to detect the presence or absence of the one or more vibration modes independent of other vibration modes.