Method and system for predicting performance of a drilling system for a given formation

• US 6,109,368 A
• Filed: 11/13/1998
• Issued: 08/29/2000
• Est. Priority Date: 03/25/1996
• Status: Expired due to Term

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Dresser Industries Incorporated (Halliburton Company)
• Inventors: Mathews, Oliver III, Murrell, Kelley M., King, William W., Goldman, William A., Weaver, Gary E., Smith, Lee Morgan, Arab, Kambiz
• Primary Examiner(s): DANG, HOANG C
• Application Number:
  US09/192,389
• Time in Patent Office: 655 Days
• Field of Search: 175/39, 175/40, 175/57, 175/24, 702/9
• US Class Current: 175/39
• CPC Class Codes: E21B 12/02 Wear indicators
• CPC Class Codes: E21B 2200/22 Fuzzy logic, artificial intelligence, neural networks or the like
• 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 44/005 Below-ground automatic control systems
• 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

Abstract

A method and apparatus for predicting the performance of a drilling system for the drilling of a well bore in a given formation includes generating a geology characteristic of the formation per unit depth according to a prescribed geology model, obtaining specifications of proposed drilling equipment for use in the drilling of the well bore, and predicting a drilling mechanics in response to the specifications as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model. The geology characteristic includes at least rock strength. The specifications includes at least a bit specification of a recommended drill bit. Lastly, the predicted drilling mechanics include at least one of bit wear, mechanical efficiency, power, and operating parameters. A display is provided for generating a display of the geology characteristic and predicted drilling mechanics per unit depth, including either a display monitor or a printer.

Claims

1. An apparatus for predicting the performance of a drilling system for the drilling of a well bore in a given formation, said prediction apparatus comprising:

means for generating a geology characteristic of the formation per unit depth according to a prescribed geology model and outputting signals representative of the geology characteristic, the geology characteristic including at least rock strength;

means for inputting specifications of proposed drilling equipment for use in the drilling of the well bore, the specifications including at least a bit specification of a recommended drill bit; and

means for determining a predicted drilling mechanics in response to the specifications of the proposed drilling equipment as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model and outputting signals representative of the predicted drilling mechanics, the predicted drilling mechanics including at least one of the following selected from the group consisting of bit wear, mechanical efficiency, power, and operating parameters.

2. The apparatus of claim 1, further comprising:

means responsive to the geology characteristic output signals and the predicted drilling mechanics output signals for generating a display of the geology characteristic and predicted drilling mechanics per unit depth.

3. The apparatus of claim 2, wherein said display generating means includes a display monitor.

4. The apparatus of claim 2, wherein said display generating means includes a printer, further wherein the display of the geology characteristic and predicted drilling mechanics per unit depth includes a printout.

5. The apparatus of claim 1, wherein

said geology characteristic generating means further generates at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity.

6. The apparatus of claim 1, wherein

said proposed drilling equipment input specification means further includes inputting at least one additional specification of proposed drilling equipment selected from the group consisting of down hole motor, top drive motor, rotary table motor, mud system, and mud pump.

7. The apparatus of claim 1, wherein the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

8. The apparatus of claim 7, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

9. The apparatus of claim 1, wherein

said geology characteristic generating means further generates at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity,

said proposed drilling equipment input specification means further includes inputting at least one additional specification of proposed drilling equipment selected from the group consisting of down hole motor, top drive motor, rotary table motor, mud system, and mud pump, and

the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque,

said apparatus further comprising:

means responsive to the geology characteristic output signals and the predicted drilling mechanics output signals for generating a display of the geology characteristic and predicted drilling mechanics per unit depth.

10. The apparatus of claim 9, wherein said display generating means includes a display monitor.

11. The apparatus of claim 9, wherein said display generating means includes a printer, further wherein the display of the geology characteristic and predicted drilling mechanics per unit depth includes a printout.

12. The apparatus of claim 1, further comprising:

means responsive to a predicted drilling mechanics output signal for controlling a parameter in an actual drilling of the well bore with the drilling system, the parameter including at least one selected from the group consisting of weight-on-bit, rpm, pump flow rate, and hydraulics.

13. The apparatus of claim 2, wherein

the display of the geology characteristic includes at least one graphical representation selected from the group consisting of a curve representation, a percentage graph representation, and a band representation, and

the display of the predicted drilling mechanics includes at least one graphical representation selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

14. The apparatus of claim 13, further wherein the at least one graphical representation of the geology characteristic and the at least one graphical representation of the predicted drilling mechanics are color coded.

15. The apparatus of claim 13, wherein said display generating means includes a display monitor.

16. The apparatus of claim 13, wherein said display generating means includes a printer, further wherein the display of the geology characteristic and predicted drilling mechanics per unit depth includes a printout.

17. The apparatus of claim 13, wherein

said geology characteristic generating means further generates at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity, and

the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

18. The apparatus of claim 17, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

19. The apparatus of claim 17, wherein

log data is expressed in the form of a curve representation, the log data including any log suite sensitive to lithology and porosity,

lithology is expressed in the form of a percentage graph for use in identifying different types of rock within the given formation, the percentage graph illustrating a percentage of each type of rock at a given depth as determined from any log suite sensitive to lithology, and

porosity is expressed in the form of a curve representation, the porosity being determined from any log suite sensitive to porosity.

20. The apparatus of claim 19, wherein

the lithology percentage graph is color coded.

21. The apparatus of claim 13, wherein

rock strength is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

22. The apparatus of claim 21, further wherein

the curve representation of rock strength includes confined rock strength and unconfined rock strength, further wherein an area between respective curves of confined rock strength and unconfined rock strength is graphically illustrated and represents an increase in rock strength as a result of a confining stress.

23. The apparatus of claim 21, further wherein

the band representation of rock strength provides a graphical illustration indicative of a discrete range of rock strength at a given depth.

24. The apparatus of claim 23, further wherein

the band representation of the rock strength is color coded, including a first color representative of a soft rock strength range, a second color representative of a hard rock strength range, and additional colors representative of one or more intermediate rock strength ranges.

25. The apparatus of claim 24, still further wherein

blue is indicative of the soft rock strength range, red is indicative of the hard rock strength range, and yellow is indicative of an intermediate rock strength range.

26. The apparatus of claim 17, wherein

shale plasticity is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

27. The apparatus of claim 26, wherein

the curve representation of shale plasticity includes at least two curves of shale plasticity parameters selected from the group consisting of water content, clay type, and clay volume, further wherein shale plasticity is determined from water content, clay type, and clay volume according to a prescribed shale plasticity model.

28. The apparatus of claim 26, wherein

the curve representation of shale plasticity is color coded.

29. The apparatus of claim 26, wherein

the band representation of the shale plasticity provides a graphical illustration indicative of a discrete range of shale plasticity at a given depth.

30. The apparatus of claim 29, further wherein

the band representation of the shale plasticity is color coded, including a first color representative of a low shale plasticity range, a second color representative of a high shale plasticity range, and additional colors representative of one or more intermediate shale plasticity ranges.

31. The apparatus of claim 30, still further wherein

blue is indicative of the low shale plasticity range, red is indicative of the high shale plasticity range, and yellow is indicative of an intermediate shale plasticity range.

32. The apparatus of claim 13, wherein

bit wear is determined as a function of cumulative work done according to a prescribed bit wear model.

33. The apparatus of claim 32, wherein

bit wear is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation.

34. The apparatus of claim 33, wherein

the curve representation of bit wear may include bit work expressed as specific energy level at the bit, cumulative work done by the bit, and optional work losses due to abrasivity.

35. The apparatus of claim 32, wherein

bit wear is expressed as a graphically illustrated percentage graph indicative of a bit wear condition at a given depth.

36. The apparatus of claim 35, further wherein

the graphically illustrated percentage graph of bit wear is color coded, including a first color representative of expired bit life, and a second color representative of remaining bit life.

37. The apparatus of claim 36, still further wherein

the first color is red and the second color is green.

38. The apparatus of claim 13, wherein

bit mechanical efficiency is determined as a function of a torque/weight-on-bit signature for the given bit according to a prescribed mechanical efficiency model.

39. The apparatus of claim 38, wherein

wherein bit mechanical efficiency is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation.

40. The apparatus of claim 39, wherein

the curve representation of bit mechanical efficiency includes total torque and cutting torque at the bit.

41. The apparatus of claim 39, wherein

the percentage graph representation of bit mechanical efficiency graphically illustrates total torque, total torque including cutting torque and frictional torque components.

42. The apparatus of claim 41, further wherein

the graphically illustrated percentage graph representation of bit mechanical efficiency is color coded, including a first color for illustrating cutting torque, a second color for illustrating frictional unconstrained torque, and a third color for illustrating frictional constrained torque.

43. The apparatus of claim 42, still further wherein

the first color is blue, the second color is yellow, and the third color is red.

44. The apparatus of claim 38, wherein

mechanical efficiency is further represented in the form of a percentage graph illustrating drilling system operating constraints which have an adverse impact upon mechanical efficiency, the drilling system operating constraints corresponding to constraints which result in an occurrence of frictional constrained torque, the percentage graph further for indicating a corresponding percentage of impact that each constraint has upon the frictional constrained torque component of the mechanical efficiency at a given depth.

45. The apparatus of claim 44, further wherein

the drilling system operating constraints can include maximum torque-on-bit (TOB), maximum weight-on-bit (WOB), minimum revolution-per-minute (RPM), maximum penetration rate (ROP), in any combination, and an unconstrained condition.

46. The apparatus of claim 45, further wherein

the percentage graph representation of drilling system operating constraints on mechanical efficiency is color coded, including different colors for identifying different constraints.

47. The apparatus of claim 13, wherein

power is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation.

48. The apparatus of claim 47, wherein

the curve representation for power includes power limit and operating power level, the power limit corresponding to a maximum power to be applied to the bit and the operating power level including at least one of the following selected from the group consisting of constrained operating power level, recommended operating power level, and predicted operating power level.

49. The apparatus of claim 48, further wherein

a difference between the power limit and operating power level curves is indicative of a constraint.

50. The apparatus of claim 47, wherein

power is further represented in the form of a percentage graph representation illustrating drilling system operating constraints which have an adverse impact upon power, the drilling system operating constraints corresponding to those constraints which result in a power loss, the power constraint percentage graph further for indicating a corresponding percentage of impact that each constraint has upon the power at a given depth.

51. The apparatus of claim 50, wherein

the percentage graph representation of drilling system operating constraints on power is color coded, including different colors for identifying different constraints.

52. The apparatus of claim 51, further wherein

red is used to identify a maximum ROP, blue is used to identify a maximum RPM, and dark blue is used to identify an unconstrained condition.

53. The apparatus of claim 13, wherein

operating parameters are expressed in the form of a curve representation.

54. The apparatus of claim 2, further comprising:

means for generating a display of details of proposed drilling equipment, the details of proposed drilling equipment to be displayed along with the geology characteristic and predicted drilling mechanics, the proposed drilling equipment including at least one recommended bit selection used in predicting the performance of the drilling system.

55. The apparatus of claim 54, wherein

the proposed drilling equipment further includes at least one additional proposed drilling equipment selected from the group consisting of down hole motor, top drive motor, rotary table motor, mud system, and mud pump.

56. The apparatus of claim 54, wherein

first and second bit selections are recommended for use in a predicted performance of the drilling of the well bore, further wherein the first and second bit selections are identified with respective first and second identifiers, the first and second identifiers being displayed with the geology characteristic and predicted drilling mechanics, further wherein the positioning of the first and second identifiers on the display is selected to correspond with portions of the predicted performance to which the first and second bit selections apply, respectively.

57. The apparatus of claim 56, wherein

the display further includes an illustration of each recommended bit selection and corresponding bit specifications.

58. The apparatus of claim 2, further comprising:

a bit selection change indicator for indicating that a change in bit selection from a first recommended bit selection to a second recommended bit selection is required at a given depth, said bit selection change indicator for being displayed on the display of geology characteristics and predicted drilling mechanics.

59. A method for predicting the performance of a drilling system for the drilling of a well bore in a given formation, said prediction method comprising the steps of:

generating a geology characteristic of the formation per unit depth according to a prescribed geology model and outputting signals representative of the geology characteristic, the geology characteristic including at least rock strength;

obtaining specifications of proposed drilling equipment for use in the drilling of the well bore, the specifications including at least a bit specification of a recommended drill bit; and

determining a predicted drilling mechanics in response to the specifications of the proposed drilling equipment as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model and outputting signals representative of the predicted drilling mechanics, the predicted drilling mechanics including at least one of the following selected from the group consisting of bit wear, mechanical efficiency, power, and operating parameters.

60. The method of claim 59, further comprising the step of:

generating a display of the geology characteristic and predicted drilling mechanics per unit depth in response to the geology characteristic output signals and the predicted drilling mechanics output signals.

61. The method of claim 60, wherein generating a display includes using a display monitor.

62. The method of claim 60, wherein generating a display includes using a printer for providing a printout of the geology characteristic and predicted drilling mechanics per unit depth.

63. The method of claim 59, wherein

generating the geology characteristic further includes generating at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity.

64. The method of claim 59, wherein

obtaining proposed drilling equipment specifications further includes obtaining at least one additional specification of proposed drilling equipment selected from the group consisting of down hole motor, top drive motor, rotary table motor, mud system, and mud pump.

65. The method of claim 59, wherein the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

66. The method of claim 65, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

67. The method of claim 59, further comprising the step of controlling a parameter in an actual drilling of the well bore with the drilling system in response to a predicted drilling mechanics output signal, the parameter including at least one selected from the group consisting of weight-on-bit, rpm, pump flow rate, and hydraulics.

68. The method of claim 60, wherein

displaying of the geology characteristic includes displaying at least one graphical plot selected from the group consisting of a curve representation, a percentage graph representation, and a band representation, and

displaying of the predicted drilling mechanics includes displaying at least one graphical plot selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

69. The method of claim 68, further wherein the at least one graphical plot of the geology characteristic and the at least one graphical plot of the predicted drilling mechanics are color coded.

70. The method of claim 68, wherein displaying includes using a display monitor.

71. The method of claim 68, wherein displaying includes using a printer for providing a printout of the geology characteristic and predicted drilling mechanics per unit depth.

72. The method of claim 68, wherein

generating the geology characteristic further includes generating at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity, and

the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

73. The method of claim 72, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

74. A method for drilling a series of well bores in a given formation for a given drilling program with the use of a given drilling system and an apparatus for predicting the performance of the drilling system, the prediction apparatus having a prescribed set of geology and drilling mechanics models and further having optimization, prediction, and calibration modes of operation, the prediction apparatus further comprising a means for generating a geology characteristic of the formation per unit depth according to the prescribed geology model and outputting signals representative of the geology characteristic, the geology characteristic including at least rock strength, a means for inputting specifications of proposed drilling equipment for use in the drilling of a well bore, the specifications including at least a bit specification of a recommended drill bit, and a means for determining a predicted drilling mechanics in response to the specifications of the proposed drilling equipment as a function of the geology characteristic per unit depth according to the prescribed drilling mechanics model and outputting signals representative of the predicted drilling mechanics, the predicted drilling mechanics including at least one of the following selected from the group consisting of bit wear, mechanical efficiency, power, and operating parameters, said method comprising the steps of:

(a) generating a predicted drilling performance for drilling of a given well bore in accordance with the prescribed set of geology and drilling mechanics prediction models using at least one of the following modes selected from the group consisting of the optimization mode and the prediction mode, the predicted drilling performance including predicted drilling mechanics measurements;

(b) deciding whether or not to obtain actual drilling mechanics measurements during the drilling of the given well bore;

(c) if obtaining actual drilling mechanics measurements, then drilling the given well bore with the drilling system using the predicted drilling performance as a guide and obtaining actual drilling mechanics measurements;

(c-1) comparing the actual drilling mechanics measurements to the predicted drilling mechanics measurements using the calibration mode;

(c-2) if the comparison of the actual drilling mechanics measurements to the predicted drilling mechanics measurements are acceptable, then advancing to step (e); and

(c-3) if the comparison of the actual drilling mechanics measurements to the predicted drilling mechanics measurements are not acceptable, then fine tuning at least one of the geology and drilling mechanics models using the calibration mode and advancing to step (e);

(d) if not obtaining actual drilling mechanics measurements, then drilling the given well bore with the drilling system using the predicted drilling performance as a guide and without obtaining actual drilling mechanics measurements; and

(e) determining if any further well bores of the series of well bores remain to be drilled and if yes, then returning to step (a) with respect to the drilling of a subsequent well bore in the series of well bores, and if no, then ending the drilling of the series of well bores.

75. A computer program stored on a computer-readable medium for execution by a computer for predicting the performance of a drilling system in the drilling of a well bore of a given formation, said computer program comprising:

instructions for generating a geology characteristic of the formation per unit depth according to a prescribed geology model and outputting signals representative of the geology characteristic, the geology characteristic including at least rock strength;

instructions for obtaining specifications of proposed drilling equipment for use in the drilling of the well bore, the specifications including at least a bit specification of a recommended drill bit; and

instructions for determining a predicted drilling mechanics in response to the specifications of the proposed drilling equipment as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model and outputting signals representative of the predicted drilling mechanics, the predicted drilling mechanics including at least one of the following selected from the group consisting of bit wear, mechanical efficiency, power, and operating parameters.

76. The computer program of claim 75, further comprising:

instructions for generating a display of the geology characteristic and predicted drilling mechanics per unit depth in response to the geology characteristic output signals and the predicted drilling mechanics output signals.

77. The computer program of claim 76, wherein generating a display includes using a display monitor.

78. The computer program of claim 76, wherein generating a display includes using a printer for providing a printout of the geology characteristic and predicted drilling mechanics per unit depth.

79. The computer program of claim 75, wherein

generating the geology characteristic further includes generating at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity.

80. The computer program of claim 75, wherein

obtaining proposed drilling equipment specifications further includes obtaining at least one additional specification of proposed drilling equipment selected from the group consisting of down hole motor, top drive motor, rotary table motor, mud system, and mud pump.

81. The computer program of claim 75, wherein the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

82. The computer program of claim 81, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

83. The computer program of claim 75, further comprising

instructions for controlling a parameter in an actual drilling of the well bore with the drilling system in response to a predicted drilling mechanics output signal, the parameter including at least one selected from the group consisting of weight-on-bit, rpm, pump flow rate, and hydraulics.

84. The computer program of claim 76, wherein

displaying of the geology characteristic includes displaying at least one graphical plot selected from the group consisting of a curve representation, a percentage graph representation, and a band representation, and

displaying of the predicted drilling mechanics includes displaying at least one graphical plot selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

85. The computer program of claim 84, further wherein the at least one graphical plot of the geology characteristic and the at least one graphical plot of the predicted drilling mechanics are color coded.

86. The computer program of claim 84, wherein displaying includes using a display monitor.

87. The computer program of claim 84, wherein displaying includes using a printer for providing a printout of the geology characteristic and predicted drilling mechanics per unit depth.

88. The computer program of claim 84, wherein

generating the geology characteristic further includes generating at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity, and

the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

89. A display of predicted performance of a drilling system suitable for use as guidance in the drilling of a well bore in a given formation, said display comprising:

a geology characteristic of the formation per unit depth, said geology characteristic having been obtained according to a prescribed geology model and including at least rock strength;

specifications of proposed drilling equipment for use in the drilling of the well bore, said specifications including at least a bit specification of a recommended drill bit; and

a predicted drilling mechanics, said predicted drilling mechanics having been determined in response to said specifications of the proposed drilling equipment as a function of said geology characteristic per unit depth according to a prescribed drilling mechanics model, said predicted drilling mechanics including at least one of the following selected from the group consisting of bit wear, mechanical efficiency, power, and operating parameters.

90. The display of claim 89, wherein said display is disposed upon a display monitor.

91. The display of claim 89, wherein said display is disposed on a printout.

92. The display of claim 89, wherein

said geology characteristic includes at least one graphical representation selected from the group consisting of a curve representation, a percentage graph representation, and a band representation, and

said display of the predicted drilling mechanics includes at least one graphical representation selected from the group consisting of a curve representation, a percentage graph representation, and a band representation.

93. The display of claim 92, further wherein the at least one graphical representation of said geology characteristic and the at least one graphical representation of said predicted drilling mechanics are color coded.

94. The display of claim 92, wherein

said geology characteristic further includes at least one of the following additional characteristics selected from the group consisting of log data, lithology, porosity, and shale plasticity, and

the operating parameters include at least one of the following selected from the group consisting of weight-on-bit, rotary rpm (revolutions-per-minute), cost, rate of penetration, and torque.

95. The display of claim 94, further wherein rate of penetration includes instantaneous rate of penetration (ROP) and average rate of penetration (ROP-AVG).

96. The display of claim 94, wherein

log data is expressed in the form of a curve representation, the log data including any log suite sensitive to lithology and porosity,

lithology is expressed in the form of a percentage graph for use in identifying different types of rock within the given formation, the percentage graph illustrating a percentage of each type of rock at a given depth as determined from any log suite sensitive to lithology,

porosity is expressed in the form of a curve representation, the porosity being determined from any log suite sensitive to porosity,

rock strength is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation, a percentage graph representation, and a band representation

wherein the curve representation of rock strength includes confined rock strength and unconfined rock strength, further wherein an area between respective curves of confined rock strength and unconfined rock strength is graphically illustrated and represents an increase in rock strength as a result of a confining stress,

further wherein the band representation of rock strength provides a graphical illustration indicative of a discrete range of rock strength at a given depth,

shale plasticity is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation, a percentage graph representation, and a band representation,

wherein the curve representation of shale plasticity includes at least two curves of shale plasticity parameters selected from the group consisting of water content, clay type, and clay volume, further wherein shale plasticity is determined from water content, clay type, and clay volume according to a prescribed shale plasticity model,

wherein the band representation of the shale plasticity provides a graphical illustration indicative of a discrete range of shale plasticity at a given depth.

97. The display of claim 96, still further wherein

lithology is color coded,

rock strength is color coded, the band representation including a first color representative of a soft rock strength range, a second color representative of a hard rock strength range, and additional colors representative of one or more intermediate rock strength ranges, further wherein blue is indicative of the soft rock strength range, red is indicative of the hard rock strength range, and yellow is indicative of an intermediate rock strength range,

shale plasticity is color coded, the band representation of the shale plasticity including a first color representative of a low shale plasticity range, a second color representative of a high shale plasticity range, and additional colors representative of one or more intermediate shale plasticity ranges, further wherein blue is indicative of the low shale plasticity range, red is indicative of the high shale plasticity range, and yellow is indicative of an intermediate shale plasticity range.

98. The display of claim 94, wherein

bit wear is determined as a function of cumulative work done according to a prescribed bit wear model, further wherein bit wear is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation,

wherein the curve representation of bit wear may include bit work expressed as specific energy level at the bit, cumulative work done by the bit, and optional work losses due to abrasivity, and

wherein the percentage graph representation of bit wear is indicative of a bit wear condition at a given depth,

mechanical efficiency is determined as a function of a torque/weight-on-bit signature for the given bit according to a prescribed mechanical efficiency model, wherein mechanical efficiency is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation,

wherein the curve representation of mechanical efficiency includes total torque and cutting torque at the bit, and

the percentage graph representation of mechanical efficiency graphically illustrates total torque, total torque including cutting torque and frictional torque components,

mechanical efficiency further being represented in the form of a percentage graph illustrating drilling system operating constraints which have an adverse impact upon mechanical efficiency, the drilling system operating constraints corresponding to constraints which result in an occurrence of frictional constrained torque, the percentage graph further for indicating a corresponding percentage of impact that each constraint has upon the frictional constrained torque component of the mechanical efficiency at a given depth, wherein the drilling system operating constraints can include maximum torque-on-bit (TOB), maximum weight-on-bit (WOB), minimum revolution-per-minute (RPM), maximum penetration rate (ROP), in any combination, and an unconstrained condition,

power is expressed in the form of at least one of the following representations selected from the group consisting of a curve representation and a percentage graph representation, wherein

the curve representation for power includes power limit and operating power level, the power limit corresponding to a maximum power to be applied to the bit and the operating power level including at least one of the following selected from the group consisting of constrained operating power level, recommended operating power level, and predicted operating power level, wherein a difference between the power limit and operating power level curves is indicative of a constraint,

power is further represented in the form of a percentage graph representation illustrating drilling system operating constraints which have an adverse impact upon power, the drilling system operating constraints corresponding to those constraints which result in a power loss, the power constraint percentage graph further for indicating a corresponding percentage of impact that each constraint has upon the power at a given depth,

operating parameters are expressed in the form of a curve representation.

99. The display of claim 98, further wherein

the percentage graph representation of bit wear is color coded, including a first color representative of expired bit life, and a second color representative of remaining bit life, the first color including red and the second color including green,

the percentage graph representation of mechanical efficiency is color coded, including a first color for illustrating cutting torque, a second color for illustrating frictional unconstrained torque, and a third color for illustrating frictional constrained torque, the first color including blue, the second color including yellow, and the third color including red,

the percentage graph representation of drilling system operating constraints on mechanical efficiency is color coded, including different colors for identifying different constraints,

the percentage graph representation of drilling system operating constraints on power is color coded, including different colors for identifying different constraints,

wherein red is used to identify a maximum ROP, blue is used to identify a maximum RPM, and dark blue is used to identify an unconstrained condition.

100. The display of claim 89, further comprising:

details of proposed drilling equipment, said details of proposed drilling equipment to be displayed along with the geology characteristic and predicted drilling mechanics, the proposed drilling equipment including at least one recommended bit selection used in predicting the performance of the drilling system.

101. The display of claim 100, wherein

first and second bit selections are recommended for use in a predicted performance of the drilling of the well bore, further wherein the first and second bit selections are identified with respective first and second identifiers, the first and second identifiers being displayed with the geology characteristic and predicted drilling mechanics, further wherein a positioning of the first and second identifiers on said display is selected to correspond with portions of the predicted performance to which the first and second bit selections apply, respectively.

102. The display of claim 101, further comprising:

a bit selection change indicator for indicating that a change in bit selection from a first recommended bit selection to a second recommended bit selection at a given depth is required, said bit selection change indicator being displayed on said display with said geology characteristics and predicted drilling mechanics.