Drill bit dysfunction identification based on compact torsional behavior encoding

Abstract

A method comprises acquiring measurements of a force and a rotational velocity experienced by a drill bit while the drill bit is positioned in a wellbore; and identifying, by at least one processor, a type of dysfunction experienced by the drill bit based on a relationship of the measurement of the force and a measurement of the rotational velocity.

1 . A method comprising:
 acquiring measurements of a force and a rotational velocity experienced by a drill bit while the drill bit is positioned in a wellbore; and   identifying, by at least one processor, a type of dysfunction experienced by the drill bit based on a relationship of the measurement of the force and a measurement of the rotational velocity.   
     
     
         2 . The method of  claim 1 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction while the drill bit is positioned in the wellbore. 
     
     
         3 . The method of  claim 2 , further comprising:
 performing the following operations while the drill bit is positioned in the wellbore,
 communicating the measurements to the at least one processor; and 
 mitigating the type of dysfunction. 
   
     
     
         4 . The method of  claim 3 , wherein the at least one processor is at a surface of the wellbore. 
     
     
         5 . The method of  claim 4 , wherein communicating the measurements comprises communicating the measurements to the at least one processor at the surface of the wellbore in real time. 
     
     
         6 . The method of  claim 1 , wherein mitigating the type of dysfunction comprises adjusting a parameter of at least one of drilling and the drill bit. 
     
     
         7 . The method of  claim 6 , wherein the parameter comprises at least one of the rotational velocity, a weight on bit, and a torque on bit. 
     
     
         8 . The method of  claim 1 , wherein the dysfunction comprises a stick-slip that includes at least one of a cutting-induced stick-slip, a friction-induced stick-slip, and a pipe-induced stick slip. 
     
     
         9 . The method of  claim 1 , wherein the dysfunction comprises a vibration. 
     
     
         10 . The method of  claim 9 , wherein the vibration comprises at least one of a torsional vibration and a torsional oscillation. 
     
     
         11 . The method of  claim 9 , wherein the vibration comprises at least one of a high-frequency torsional oscillation and a low-frequency torsional oscillation. 
     
     
         12 . The method of  claim 9 , wherein the vibration comprises a three-dimensional vibration. 
     
     
         13 . The method of  claim 1 , wherein the force comprises at least one of a weight on bit (WOB) and a torque on bit (TOB). 
     
     
         14 . The method of  claim 13 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction based on at least one of a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity. 
     
     
         15 . The method of  claim 13 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction based on a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity. 
     
     
         16 . A non-transitory, machine-readable medium having instructions stored thereon that are executable by a processor to perform operations comprising:
 acquiring measurements of a force and a rotational velocity experienced by a drill bit while the drill bit is positioned in a wellbore; and   identifying, by at least one processor, a type of dysfunction experienced by the drill bit based on a relationship of the measurement of the force and a measurement of the rotational velocity.   
     
     
         17 . The non-transitory, machine-readable medium of  claim 16 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction while the drill bit is positioned in a wellbore. 
     
     
         18 . The non-transitory, machine-readable medium of  claim 17 , further comprising:
 performing the following operations while the drill bit is positioned in a wellbore, communicating the measurements to the at least one processor; and
 mitigating the type of dysfunction. 
   
     
     
         19 . The non-transitory, machine-readable medium of  claim 18 , wherein the at least one processor is at a surface of the wellbore. 
     
     
         20 . The non-transitory, machine-readable medium of  claim 19 , wherein communicating the measurements comprises communicating the measurements to the at least one processor at the surface of the wellbore in real time. 
     
     
         21 . The non-transitory, machine-readable medium of  claim 16 , wherein mitigating the type of dysfunction comprises adjusting a parameter of at least one of drilling and the drill bit. 
     
     
         22 . The non-transitory, machine-readable medium of  claim 21 , wherein the parameter comprises at least one of the rotational velocity, a weight on bit, and a torque on bit. 
     
     
         23 . The non-transitory, machine-readable medium of  claim 16 , wherein the dysfunction comprises a stick-slip that includes at least one of a cutting-induced stick-slip, a friction-induced stick-slip, and a pipe-induced stick slip. 
     
     
         24 . The non-transitory, machine-readable medium of  claim 16 , wherein the dysfunction comprises a vibration. 
     
     
         25 . The non-transitory, machine-readable medium of  claim 24 , wherein the vibration comprises at least one of a torsional vibration and a torsional oscillation. 
     
     
         26 . The non-transitory, machine-readable medium of  claim 24 , wherein the vibration comprises at least one of a high-frequency torsional oscillation and a low-frequency torsional oscillation. 
     
     
         27 . The non-transitory, machine-readable medium of  claim 24 , wherein the vibration comprises a three-dimensional vibration. 
     
     
         28 . The non-transitory, machine-readable medium of  claim 16 , wherein the force comprises at least one of a weight on bit (WOB) and a torque on bit (TOB). 
     
     
         29 . The non-transitory, machine-readable medium of  claim 28 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction based on at least one of a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity. 
     
     
         30 . The non-transitory, machine-readable medium of  claim 28 , wherein identifying the type of dysfunction comprises identifying the type of dysfunction based on a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity. 
     
     
         31 . A system comprising:
 at least one processor; and   a non-transitory, machine-readable medium having instructions stored thereon that are executable by the at least one processor to cause the at least one processor to,
 acquire measurements of a force and a rotational velocity experienced by a drill bit while the drill bit is positioned in a wellbore; and 
 identify a type of dysfunction experienced by the drill bit based on a relationship of the measurement of the force and a measurement of the rotational velocity. 
   
     
     
         32 . The system of  claim 31 , wherein the instructions to cause the at least one processor to identify the type of dysfunction comprise instructions to cause the at least one processor to identify the type of dysfunction while the drill bit is positioned in a wellbore. 
     
     
         33 . The system of  claim 32 , further comprising:
 the drill bit to drill the wellbore,
 wherein the instructions comprise instructions executable by the processor to cause the processor to,
 perform the following operations while the drill bit is positioned in a wellbore,
 communicate the measurements to the at least one processor; and 
 mitigate the type of dysfunction. 
 
 
   
     
     
         34 . The system of  claim 33 , wherein the at least one processor is at a surface of the wellbore. 
     
     
         35 . The system of  claim 34 , wherein the instructions to cause the at least one processor to communicate the measurements comprises instructions to cause the at least one processor to communicate the measurements to the at least one processor at the surface of the wellbore in real time. 
     
     
         36 . The system of  claim 31 , wherein the instructions to cause the at least one processor to mitigate the type of dysfunction comprises the instructions to cause the at least one processor to adjust a parameter of at least one of drilling and the drill bit. 
     
     
         37 . The system of  claim 36 , wherein the parameter comprises at least one of the rotational velocity, a weight on bit, and a torque on bit. 
     
     
         38 . The system of  claim 31 , wherein the dysfunction comprises a stick-slip that includes at least one of a cutting-induced stick-slip, a friction-induced stick-slip, and a pipe-induced stick slip. 
     
     
         39 . The system of  claim 31 , wherein the dysfunction comprises a vibration. 
     
     
         40 . The system of  claim 39 , wherein the vibration comprises at least one of a torsional vibration and a torsional oscillation. 
     
     
         41 . The system of  claim 39 , wherein the vibration comprises at least one of a high-frequency torsional oscillation and a low-frequency torsional oscillation. 
     
     
         42 . The system of  claim 39 , wherein the vibration comprises a three-dimensional vibration. 
     
     
         43 . The system of  claim 31 , wherein the force comprises at least one of a weight on bit (WOB) and a torque on bit (TOB). 
     
     
         44 . The system of  claim 43 , wherein the instructions to cause the at least one processor to identify the type of dysfunction comprises the instructions to cause the at least one processor to identify the type of dysfunction based on at least one of a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity. 
     
     
         45 . The system of  claim 43 , wherein the instructions to cause the at least one processor to identify the type of dysfunction comprises the instructions to cause the at least one processor to identify the type of dysfunction based on a ratio of the WOB to the rotational velocity and a ratio of the TOB to the rotational velocity.