Simulating the dynamic response of a drilling tool assembly and its application to drilling tool assembly design optimization and drilling performance optimization

• US 6,785,641 B1
• Filed: 10/11/2000
• Issued: 08/31/2004
• Est. Priority Date: 10/11/2000
• Status: Expired due to Term

• Current Assignee: Smith International Incorporated (Schlumberger NV)
• Original Assignee: Smith International Incorporated (Schlumberger NV)
• Inventors: Huang, Sujian
• Primary Examiner(s): PALADINI, ALBERT WILLIAM
• Application Number:
  US09/689,299
• Time in Patent Office: 1,420 Days
• Field of Search: 703/7, 175/45, 175/50, 702/6, 702/9
• US Class Current: 703/7
• CPC Class Codes: E21B 10/00 Drill bits specially adapted for deflecting the direction of boring E21B7/064; with means for collecting substances E21B27/00
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions

Abstract

A method for simulating the dynamic response of a drilling tool assembly is disclosed. Methods for simulating drilling tool assemblies may be used to generate a visual representation of drilling, to design drilling tool assemblies, and to optimize the drilling performance of a drilling tool assembly. One method for designing a drilling tool assembly includes simulating a dynamic response for the drilling tool assembly, adjusting a value of at least one drilling tool assembly design parameter, and repeating the simulating. The method further includes repeating the adjusting and the simulating until at least one drilling performance parameter is determined to be at an optimum value. One method for optimizing at least one drilling operating parameter for a drilling tool assembly includes simulating a dynamic response of the drilling tool assembly, adjusting the value of at least one drilling operating parameter, and repeating the simulating. The method further includes repeating the adjusting and the simulating until at least one drilling performance parameter is determined to be at an optimal value.

Claims

1. A method for optimizing a drilling tool assembly design, comprising:

simulating a dynamic response of the drilling tool assembly;

adjusting a value of at least one drilling tool assembly design parameter;

repeating the simulating;

repeating the adjusting and the simulating until at least one drilling performance parameter is determined to be at an optimal value.

2. The method of claim 1, wherein the simulating comprises,

solving for the dynamic response of the drilling tool assembly to an incremental rotation using a mechanics analysis model, and

repeating said solving for a select number of successive incremental rotations.

3. The method of claim 2, wherein said solving comprises,

constructing the mechanics analysis model of the drilling tool assembly using selected drilling tool assembly design parameters,

determining wellbore constraints from wellbore trajectory parameters, a specified bottom hole geometry, and a specified hook load,

determining loads on the drilling tool assembly for a position of the drilling tool assembly in the wellbore using at least the mechanics analysis model and the wellbore constraints, and

calculating the dynamic response of the drilling tool assembly under the loads to the incremental rotation using the mechanics analysis model.

4. The method of claim 3, wherein said solving further comprises,

redetermining the loads on the drilling tool assembly based on the calculated dynamic response to the incremental rotation,

repeating the calculating the dynamic response of the drilling tool assembly under the loads to the incremental rotation, and

repeating the redetermining and the calculating until convergence of the dynamic response is determined.

5. The method of claim 3, wherein the determining loads comprises,

determining constraint forces required to displace the drilling tool assembly from an unconstrained state to a state wherein a centerline of the drilling tool assembly substantially aligns with a centerline of a wellbore trajectory,

calculating the steady state position of the drilling tool assembly under the determined constraint forces,

redetermining constraint forces required to constrain the steady state position of the drilling tool assembly within the wellbore, and

repeating the calculating of the steady state position and the redetermining of the constraint forces until a position convergence criterion is satisfied.

6. The method of claim 4, wherein redetermining the loads comprises,

identifying, from the dynamic response, points along the drilling tool assembly which interact with the wellbore wall during the incremental rotation,

determining, from drilling tool assembly/environment interaction information, constraint forces at the points resulting from interaction with the wellbore wall, and

updating the loads to include determined constraint forces.

7. The method of claim 6, wherein redetermining the loads further comprises,

determining, from the dynamic response, drill bit parameters, and a drill bit model, cutting element interaction with a bottom of the wellbore during the incremental rotation,

determining, from drilling tool assembly/environment interaction information, cutting element interaction, and the hook load, total forces on the bit resulting from the cutting element interaction with the bottom surface of the wellbore, and

updating the loads to account for the newly calculated total forces on the bit.

8. The method of claim 1, wherein the drilling performance parameter is determined to be at an optimal value when at least one of a maximum rate of penetration, a minimum rotary torque to maintain rotation speed, and a most even weight on bit is determined to occur.

9. The method of claim 1, wherein the at least one drilling tool assembly design parameter is selected from the group of drill string design parameters, bottomhole assembly design parameters, and drill bit design parameters.

10. The method of claim 9, wherein the drill string design parameters comprise at least one of a length, an inner diameter, an outer diameter, a density, a strength, and an elasticity for at least one component in a drill string, wherein the drill string comprises at least one joint of drill pipe.

11. The method of claim 9, wherein the bottomhole assembly design parameters comprise at least one selected from the group of a length, an inner diameter, an outer diameter, a weight, a strength, and an elasticity for at least one of a plurality of components in a bottomhole assembly, adding at least one component to the bottomhole assembly, and deleting at least one component from the bottomhole assembly, wherein components in the bottomhole assembly comprise at least one of a drill collar, stabilizer, bent housing, measurement-while-drilling tool, logging-while-drilling tool, and downhole motor.

12. The method of claim 9, wherein the drill bit design parameters comprise at least one of a drill bit type, drill bit diameter, cutting element count, cutting element geometric shape, cutting element height, cutting element location, and cutting element spacing.

13. The method of claim 12, wherein the drill bit type is a roller cone drill bit, and the drill bit design parameters further comprise at least one of a number of cones, a cone profile, a number of cutting element rows on each cone, a number of cutting elements on each row, a cutting element orientation, a cutting element pitch, a cone axis offset, and a journal angle.

14. The method of claim 1, wherein the at least one drilling performance parameter is selected from the group of rate of penetration, rotary torque, rotary speed, weight on bit, lateral force on bit, ratio of forces on cones, ratio of forces between cones, distribution of forces on cutting elements, volume of formation cut, and wear on cutting elements.

15. A method for determining at least one optimal drilling operating parameter for a drilling tool assembly, comprising:

simulating a dynamic response of the drilling tool assembly;

adjusting a value of at least one drilling operating parameter;

repeating the simulating;

repeating the adjusting and the simulating until at least one drilling performance parameter is determined to be at an optimal value.

16. The method of claim 15, wherein the simulating comprises,

solving for the dynamic response of the drilling tool assembly to an incremental rotation using a mechanics analysis model, and

repeating said solving for a select number of successive incremental rotations.

17. The method of claim 16, wherein said solving comprises determining wellbore constraints on the drilling tool assembly, determining loads on the drilling tool assembly resulting from wellbore constraints, and

calculating the dynamic response of the drilling tool assembly under the loads and drilling operating parameters to the incremental rotation.

18. The method of claim 17, wherein said solving further comprises,

redetermining loads on the drilling tool assembly based on the dynamic response to the incremental rotation,

repeating the calculating the dynamic response of the drilling tool assembly under the loads to the incremental rotation, and

repeating the redetermining and calculating until convergence of the dynamic response is determined.

19. The method of claim 17, wherein the determining loads comprises,

determining constraint forces required to displace the drilling tool assembly from an unconstrained state to a state wherein a centerline of the drilling tool assembly substantially aligns with a centerline of a wellbore trajectory,

calculating the steady state position of the drilling tool assembly under the determined constraint forces,

redetermining constraint forces required to constrain the steady state position of the drilling tool assembly within the wellbore, and

repeating the calculating of the steady state position and the redetermining of the constraint forces until a position convergence criterion is satisfied.

20. The method of claim 18, wherein redetermining the loads comprises,

identifying, from the dynamic response, points along the drilling tool assembly which interact with the wellbore wall during the incremental rotation,

determining, from drilling tool assembly/environment interaction information, constraint forces at the points resulting from interaction with the wellbore wall, and

updating the loads to include determined constraint forces.

21. The method of claim 20, wherein redetermining the loads further comprises,

determining, from the dynamic response, drill bit parameters, and a drill bit model, cutting element interaction with a bottom of the wellbore during the incremental rotation,

determining, from drilling tool assembly/environment interaction information, cutting element interaction, and the hook load, total forces on the bit resulting from the cutting element interaction with the bottom surface of the wellbore, and

updating the loads to account for the newly calculated total forces on the bit.

22. The method of claim 15, wherein the at least one drilling operating parameter is selected from the group of rotary speed, rotary torque, hook load, drilling fluid viscosity, and drilling fluid density.

23. The method of claim 15, wherein the at least one drilling performance parameter is selected from the group of rate of penetration, rotary torque, rotary speed, weight on bit, lateral force on bit, ratio of forces on cones, distribution of forces on cutting elements, volume of formation cut, and wear on cutting elements.

24. The method of claim 15, wherein the at least one drilling performance parameter is determined to be at an optimal value when at least one of a maximum rate of penetration, a minimum rotary torque to maintain the rotation speed, and a most even weight on bit is determined to occur.

25. A method for designing a drilling tool assembly, comprising:

defining initial drilling tool assembly design parameters;

simulating a dynamic response of the drilling tool assembly;

adjusting a value of at least one of the drilling tool assembly design parameters;

repeating the simulating and the adjusting a selected number of times;

evaluating the dynamic responses; and

based on the evaluating, selecting desired drilling tool assembly design parameters.

26. A method for selecting drilling operating parameters for a drilling tool assembly, comprising:

simulating a dynamic response of the drilling tool assembly;

adjusting a value of at least one drilling operating parameter;

repeating the simulating;

repeating the adjusting and the simulating a selected number of times;

evaluating the dynamic responses simulated; and

based on the evaluating, selecting drilling operating parameter values.

27. A method for generating a visual representation of drilling characteristics of a drilling tool assembly drilling earth formation, the drilling tool assembly comprising at least a drill pipe and a drill bit, the method comprising:

solving for a dynamic response of the drilling tool assembly to an incremental rotation;

determining, based on the dynamic response, parameters of craters removed from a bottomhole surface of the formation due to contact of the bit with the bottomhole surface during the incremental rotation;

calculating a bottomhole geometry, wherein the craters are removed from the bottomhole surface;

repeating said solving, determining, and calculating for a selected number of successive incremental rotations; and

converting the dynamic response and the bottomhole geometry parameters into said visual representation of the drilling characteristics of the drilling tool assembly.

28. A method for generating a visual representation of drilling characteristics of a drilling tool assembly drilling an earth formation, comprising:

selecting drilling tool assembly design parameters, comprising at least a length of drill pipe, a geometry of at least one cutting element on a drill bit, and a location of the at least cutting element;

selecting drilling parameters, comprising at least a rotation speed of the drilling tool assembly and a wellbore bottomhole surface and;

selecting an earth formation to be represented as drilled;

calculating from said selected drilling tool assembly design parameters, said selected drilling parameters, and said earth formation, a dynamic response of the drilling tool assembly and a bottomhole geometry resulting from interaction between the at least one cutting element on the drill bit and the bottomhole surface;

incrementally rotating said drilling tool assembly, and repeating said calculating; and

converting said drilling tool assembly parameters and said bottomhole geometry parameters into said visual representation of the drilling characteristics of the drilling tool assembly.