Methods and systems for designing and/or selecting drilling equipment using predictions of rotary drill bit walk

• US 7,860,693 B2
• Filed: 04/18/2007
• Issued: 12/28/2010
• Est. Priority Date: 08/08/2005
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Chen, Shilin
• Primary Examiner(s): PHAN, THAI Q
• Application Number:
  US11/737,065
• Publication Number:
  US 20070192074A1
• Time in Patent Office: 1,350 Days
• Field of Search: 703/2, 703/7, 703/10, 175/331, 175/341, 175/61, 702/9
• US Class Current: 703/2
• 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 41/00 Equipment or details not covered by groups E21B15/00 - E21B40/00
• 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
• CPC Class Codes: E21B 49/003 by analysing drilling variables or conditions E21B49/005 takes precedence; systems specially adapted for monitoring a plurality of drilling variables or conditions E21B44/00
• CPC Class Codes: E21B 7/04 Directional drilling

Abstract

Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore.

Claims

1. A method for determining bit walk rate of a long gage rotary drill bit comprising:

applying a set of drilling conditions to the bit including at least bit rotational speed, rate of penetration along a bit rotational axis, and at least one characteristic of an earth formation;

applying a steer rate to the bit by tilting the bit around a fulcrum point located on a sleeve located above the bit gage, wherein the fulcrum point is defined as a contact point between the sleeve and a wellbore;

simulating, for a time interval, drilling of the earth formation by the bit under the set of drilling conditions, including calculating a steer force applied to the bit and an associated walk force;

calculating a walk rate based at least on the steer force and the walk force;

repeating the simulating successively for a predefined number of time intervals; and

calculating an average walk rate of the bit using an average steer force and an average walk force over the simulated time interval.

2. The method of claim 1 further comprising applying the steer rate in a vertical plane passing through the bit rotational axis.

3. The method of claim 1 wherein calculating the walk rate further comprises:

determining respective three dimensional locations of all cutting edges of all cutters and all gage portions in a hole coordinate system;

determining respective interactions of all cutting edges of the cutters and gage portions with the bottom hole of the formation;

calculating a cutting depth for each cutting edge and a cutting area for each cutting element;

calculating respective three dimensional forces of the cutters and projecting the forces into a hole coordinate system;

summing all of the cutter forces projected in the hole coordinate system;

projecting the summed forces into the vertical tilting plane; and

calculating the steer force in the vertical tilting plane and perpendicular to bit rotational axis.

4. The method of claim 1 wherein calculating the walk rate further comprises:

determining respective three dimensional locations of all cutting edges of all cutters and all gage portions in a hole coordinate system;

determining respective interactions of all cutting edges of the cutters and gage portions with the bottom hole of the formation;

calculating a cutting depth for each cutting edge and a cutting area for each cutting element;

calculating respective three dimensional forces of the cutters and projecting the forces into a hole coordinate system;

summing all of the cutter forces projected in the hole coordinate system;

projecting the summed forces into a plane perpendicular to the vertical tilting plane; and

calculating the walk force in the plane perpendicular to the vertical tilting plane and perpendicular to bit rotational axis.

5. The method as defined in claim 1, further comprising the walk rate, at time t, of the bit calculated by:

Walk Rate=(Steer Rate/Steer Force)×

Walk Force.

6. The method of claim 1 further comprising:

determining a bit walk angle of the long gage rotary drill bit by calculating the average bit walk rate over a pre-defined time interval under a pre-defined drilling conditions where at least the magnitude of the given steer rate is not equal to zero,

wherein if the average bit walk rate is negative, the bit walks left;

if the average bit walk rate is positive, the bit walks right; and

if the average bit walk rate is substantially close to zero, bit does not walk.

7. A method for determining bit walk rate of a long gage rotary drill bit comprising:

applying a set of drilling conditions to the bit including at least bit rotational speed, hole size and rate of penetration along a bit rotational axis and at least one characteristic of an earth formation;

applying a steer rate to the bit, wherein applying the steer rate includes tilting the bit around a fulcrum point located at a top section of the bit gage;

simulating, for a time interval, drilling of the earth formation by the bit under the set of drilling conditions, including calculating a steer moment applied to the bit and an associated walk moment;

calculating a walk rate based on the bit steer rate, the steer moment, and the walk moment;

repeating simulating drilling the earth formation for another time interval, and recalculating the steer moment, the walk moment and walk rate;

repeating the simulating successively for a predefined number of time intervals; and

calculating an average walk rate of the bit using an average steer moment and an average walk moment over the simulated time interval.

8. The method of claim 7 wherein applying the steer rate further comprises applying the steer rate in a vertical plane passing through the bit rotational axis.

9. The method of claim 7 wherein calculating the walk rate further comprises:

determining respective three dimensional locations of all cutting edges of all cutters and all gage portions in a hole coordinate system;

determining respective interactions of all cutting edges of the cutters and gage portions with the bottom hole of the formation;

calculating a cutting depth for each cutting edge and a cutting area for each cutting element;

calculating respective three dimensional forces of the cutters;

calculating the three dimensional moments of the cutting elements around a predefined point on bit axis, and projecting the moments into a hole coordinate system;

summing all of the cutter moments projected in the hole coordinate system;

projecting the summed moments into the vertical tilting plane; and

calculating the walk moment in the vertical tilting plane and perpendicular to bit rotational axis.

10. The method of claim 7 wherein calculating the walk rate further comprises:

determining respective three dimensional locations of all cutting edges of all cutters and all gage portions in a hole coordinate system;

determining respective interactions of all cutting edges of the cutters and gage portions with the bottom hole of the formation;

calculating a cutting depth for each cutting edge and a cutting area for each cutting element;

calculating respective three dimensional forces of the cutters;

calculating the three dimensional moments of the cutting elements around a predefined point on bit axis, and projecting the moments into a hole coordinate system;

summing all of the cutter moments projected in the hole coordinate system;

projecting the summed moments into a plane perpendicular to the vertical tilting plane; and

calculating the steer moment in the plane perpendicular to the vertical tilting plane and perpendicular to bit rotational axis.

11. The method as defined in claim 7, further comprising the walk rate, at time t, of the bit calculated by:

Walk Rate=(Steer Rate/Steer Moment)×

Walk Moment.

12. A method to design a long gage rotary drill bit with a desired bit walk rate comprising:

(a) determining one or more drilling conditions and one or more formation characteristics of a formation to be drilled by the bit;

(b) simulating drilling at least one portion of a wellbore having a wellbore diameter greater than the bit diameter, using the one or more drilling conditions;

(c) calculating an average bit walk rate;

(d) comparing the calculated bit walk rate to the desired walk rate;

(e) if the calculated bit walk rate does not approximately equal the desired walk rate, performing the following steps;

(f) dividing the bit body into at least an inner zone, a shoulder zone, a gage zone, an active gage zone and a passive gage zone;

(g) calculating the walk rate of each zone;

(h) calculating the walk rate of a first combined zone including the inner zone and the shoulder zone;

(i) calculating the walk rate of a second combined zone including the active gage zone and the passive gage zone;

(j) identifying the zone which has the maximal magnitude of walk rate and the zone which has the minimal magnitude of walk rate;

(h) modifying one or more structures within the zone which has the maximal magnitude of walk rate or the zone which has the minimal magnitude of the walk rate; and

(k) repeating steps (b) through (j) until the calculated bit walk rate approximately equals the desired bit walk rate.

13. The method of claim 12, wherein modifying the structure within the inner zone includes modifying at least one characteristic of the bit selected from the group consisting of the cone angle, the number of blades, the number of cutters, the location of cutters, the size of cutters, the back rake angle of each cutter, and the side rake angle of each cutter.

14. The method of claim 12, wherein modifying the structure within the shoulder zone includes modifying at least one characteristic of the bit selected from the group consisting of the number of blades, the number of cutters, the location of cutters, the size of cutters, the back rake angle of each cutter, and the side rake angle of each cutter.

15. The method of claim 12, wherein modifying the structure within the gage zone includes modifying at least one characteristic of the bit selected from the group consisting of the length of the bit gage, the number of gage cutters, the location of gage cutters, the size of the gage cutters, the back rake angle of each cutter, and side rake angle of each cutter.

16. The method of claim 12, wherein modifying the structure within the active gage zone includes modifying at least one characteristic of the bit selected from the group consisting of the length of the active gage, the number of blades, the width of each blade, the spiral angle of each blade, the diameter of the active gage and the aggressiveness of the active gage.

17. The method of claim 12, wherein modifying the structure within the passive gage zone includes modifying at least one characteristic of the bit selected from the group consisting of the length of the passive gage, the number of blades, the width of each blade, the spiral angle of each blade, the diameter of the passive gage, the number of steps of passive gage and the taper angle of the passive gage.

18. A method to find and optimize operational parameters to control bit walk of a long gage rotary drill bit during drilling of at least one portion of a wellbore comprising:

(a) determining a bit path deviation for the at least one portion of the wellbore;

(b) determining a desired bit walk rate to compensate for the bit path deviation;

(c) determining downhole formation properties at a first location and at a second location ahead of the first location in the at least one portion of the wellbore;

(d) simulating drilling with the rotary drill bit between the first location and the second location, wherein simulating drilling includes predicting a hole size greater than the bit size;

(e) during the simulation applying to the rotary drill bit a steer rate;

(f) calculating a walk rate of the rotary drill bit and comparing the calculated walk rate with the desired walk rate; and

(g) changing at least one set of the bit operational parameters and repeating steps (d) through (f) until the calculated walk rate approximately equals the desired walk rate.

19. The method of claim 18 further comprising determining optimum operational parameters to control the bit walk rate of a long gage rotary drill bit.

20. The method of claim 18 further comprising applying a second set of bit operational parameters to the rotary drill bit and continuing to simulate drilling.

21. The method of claim 18 further comprising repeating steps (a) through (g) for another portion of the wellbore.

22. The method of claim 18 further comprising designing a passive gage with an optimum taper and optimum length to reduce steer force and/or walk force on the rotary drill bit while drilling a directional well bore.

23. The method of claim 18 further comprising forming a passive gage having a taper of approximately two degrees of the rotary drill bit.

24. A method for designing a long gage rotary drill bit having a gage and corresponding bit size, the method comprising:

(a) determining one or more formation properties for use in simulating drilling with the bit;

(b) determining one or more drilling conditions for use in simulating drilling with the bit;

(c) simulating drilling using the one or more formation properties and the one or more drilling conditions, and wherein simulating drilling includes predicting a wellbore diameter greater than the bit size;

(d) calculating a walk rate based on the simulated drilling;

(e) comparing the calculated walk rate with a desired walk rate;

(f) if the calculated walk rate is not approximately equal to the desired walk rate, changing a bit geometry or changing a geometric parameter of the gage; and

(g) repeating steps (c) through (f) until the calculated walk rate approximately equals the desired walk rate.

25. The method of claim 24 wherein determining one or more formation properties includes determining whether the formation has a tendency to form holes with a larger diameter than the corresponding bit size of a rotary drill bit used to drill the formation.

26. The method of claim 24 further comprising calculating the walk rate based on a steer force and a walk force.

27. The method of claim 24 further comprising calculating the walk rate based on a steer moment and a walk moment.

28. The method of claim 24 further comprising calculating the walk rate based on an average of the walk rate calculated from the steer force and the walk force, and the walk rate calculated from the steer moment and the walk moment.

29. A long gage rotary drill bit with a desired bit walk rate prepared by a process comprising:

(a) determining one or more drilling conditions and one or more formation characteristics of a formation to be drilled by the bit;

(b) simulating drilling at least one portion of a wellbore having a wellbore diameter greater than the bit diameter, using the one or more drilling conditions;

(c) calculating an average bit walk rate;

(d) comparing the calculated bit walk rate to the desired walk rate;

(e) if the calculated bit walk rate does not approximately equal the desired walk rate, performing the following steps;

(f) dividing the bit body into at least an inner zone, a shoulder zone, a gage zone, an active gage zone and a passive gage zone;

(g) calculating the walk rate of each zone;

(h) calculating the walk rate of a first combined zone including the inner zone and the shoulder zone;

(i) calculating the walk rate of a second combined zone including the active gage zone and the passive gage zone;

(j) identifying the zone which has the maximal magnitude of walk rate and the zone which has the minimal magnitude of walk rate;

(h) modifying one or more structures within the zone which has the maximal magnitude of walk rate or the zone which has the minimal magnitude of the walk rate;

(k) repeating steps (b) through (j) until the calculated bit walk rate approximately equals the desired bit walk rate; and

(l) manufacturing the long gage rotary drill bit having the desired bit walk rate.

30. The long gage rotary drill bit of claim 29, further comprising the long gage rotary drill bit prepared by a process wherein calculating an average bit walk rate further comprises:

applying a set of drilling conditions to the bit including at least bit rotational speed, rate of penetration along a bit rotational axis, and at least one characteristic of an earth formation;

applying a steer rate to the bit by tilting the bit around a fulcrum point located on a sleeve located above the bit gage, wherein the fulcrum point is defined as a contact point between the sleeve and a wellbore;

simulating, for a time interval, drilling of the earth formation by the bit under the set of drilling conditions, including calculating a steer force applied to the bit and an associated walk force;

calculating a walk rate based at least on the steer force and the walk force;

repeating the simulating successively for a predefined number of time intervals; and

calculating an average walk rate of the bit using an average steer force and an average walk force over the simulated time interval.

31. The long gage rotary drill bit of claim 29, further comprising the long gage rotary drill bit prepared by a process wherein calculating an average bit walk rate further comprises:

applying a set of drilling conditions to the bit including at least bit rotational speed, hole size and rate of penetration along a bit rotational axis and at least one characteristic of an earth formation;

applying a steer rate to the bit, wherein applying the steer rate includes tilting the bit around a fulcrum point located at a top section of the bit gage;

simulating, for a time interval, drilling of the earth formation by the bit under the set of drilling conditions, including calculating a steer moment applied to the bit and an associated walk moment;

calculating a walk rate based on the bit steer rate, the steer moment, and the walk moment;

repeating simulating drilling the earth formation for another time interval, and recalculating the steer moment, the walk moment and walk rate;

repeating the simulating successively for a predefined number of time intervals; and

calculating an average walk rate of the bit using an average steer moment and an average walk moment over the simulated time interval.

32. A long gage rotary drill bit having a gage and corresponding bit size, prepared by a process comprising:

(a) determining one or more formation properties for use in simulating drilling with the bit;

(b) determining one or more drilling conditions for use in simulating drilling with the bit;

(c) simulating drilling using the one or more formation properties and the one or more drilling conditions, and wherein simulating drilling includes predicting a wellbore diameter greater than the bit size;

(d) calculating a walk rate based on the simulated drilling;

(e) comparing the calculated walk rate with a desired walk rate;

(f) if the calculated walk rate is not approximately equal to the desired walk rate, changing a bit geometry or changing a geometric parameter of the gage;

(g) repeating steps (c) through (f) until the calculated walk rate approximately equals the desired walk rate; and

(h) manufacturing the long gage rotary drill bit having the desired bit walk rate.