Ultra-low friction coatings for drill stem assemblies

• US 8,220,563 B2
• Filed: 08/18/2009
• Issued: 07/17/2012
• Est. Priority Date: 08/20/2008
• Status: Active Grant

• Current Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Original Assignee: ExxonMobil Research & Engineering Company (Exxon Mobil Corporation)
• Inventors: Bangaru, Narasimha-Rao Venkata, Ozekcin, Adnan, Jin, Hyun-Woo, Biediger, Erika Ann Ooten, Bailey, Jeffrey Roberts, Gupta, Vishwas, Ertas, Mehmet Deniz, Elks, William Curtis Jr.
• Primary Examiner(s): Neuder, William P
• Application Number:
  US12/583,292
• Publication Number:
  US 20100044110A1
• Time in Patent Office: 1,064 Days
• Field of Search: 175/57, 175/226, 175/320, 166/902
• US Class Current: 175/57
• CPC Class Codes: C23C 14/0605 Carbon
• CPC Class Codes: C23C 16/26 Deposition of carbon only
• CPC Class Codes: C23C 30/005 on hard metal substrates
• CPC Class Codes: E21B 17/1085 Wear protectors; Blast joints; Hard facing
• CPC Class Codes: E21B 7/046 horizontal drilling drilling with mechanical conveying means E21B7/003

Abstract

Provided are drill stem assemblies with ultra-low friction coatings for subterraneous drilling operations. In one form, the coated drill stem assemblies for subterraneous rotary drilling operations include a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly or a coiled tubing coupled to a bottom hole assembly and an ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly, wherein the coefficient of friction of the ultra-low friction coating is less than or equal to 0.15. The coated drill stem assemblies disclosed herein provide for reduced friction, vibration (stick-slip and torsional), abrasion and wear during straight hole or directional drilling to allow for improved rates of penetration and enable ultra-extended reach drilling with existing top drives.

Claims

1. A coated drill stem assembly for subterraneous rotary drilling operations comprising:

a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly or a coiled tubing coupled to a bottom hole assembly and

an ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly, wherein the coefficient of friction of the ultra-low friction coating is less than or equal to 0.15,

wherein the ultra-low friction coating is diamond-like-carbon (DLC) and provides resistance to casing wear at least 3 times greater than an uncoated drill stem assembly.

2. The coated drill stem assembly of claim 1, wherein the diamond-like-carbon (DLC) is chosen from to-C, ta-C:

H, DLCH, PLCH, GLCH, Si-DLC, N-DLC, O-DLC, B-DLC, Me-DLC, F-DLC and combinations thereof.

3. The coated drill stem assembly of claim 1, wherein the ultra-low friction coating provides a surface energy less than 1 J/m² to mitigate sticking or balling by rock cuttings during subterraneous rotary drilling operations.

4. The coated drill stem assembly of claim 3, wherein the ultra-low friction coating provides a surface energy less than 0.1 J/m².

5. The coated drill stem assembly of claim 3, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides a hardness greater than 400 VHN to provide for drilling in shales with water based muds and the use of spiral stabilizers.

6. The coated drill stem assembly of claim 1, wherein the water contact angle of the ultra-low friction coating is greater than 60 degrees.

7. The coated drill stem assembly of claim 6, wherein the water contact angle of the ultra-low friction coating is greater than 80 degrees.

8. The coated drill stem assembly of claim 1, wherein the ultra-low friction coating comprises a single ultra-low friction layer or two or more ultra-low friction layers.

9. The coated drill stem assembly of claim 8, wherein the ultra-low friction coating comprises two or more ultra-low friction layers, wherein the two or more ultra-low friction layers are of substantially the same or different ultra-low friction coatings.

10. The coated drill stem assembly of claim 8, wherein the thickness of the single ultra-low friction layer and of each layer of the two or more ultra-low friction layers ranges from 0.5 microns to 5000 microns.

11. The coated drill stem assembly of claim 8, wherein the ultra-low friction coating further comprises one or more buffer layers.

12. The coated drill stem assembly of claim 11, wherein the one or more buffer layers are interposed between the outer surface of the body assembly and the single ultra-low friction layer or the two or more ultra-low friction layers.

13. The coated drill stem assembly of claim 11, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

14. The coated drill stem assembly of claim 1, wherein the drill string comprises one or more components chosen from drill pipe, tool joints, transition pipe between the drill string and bottom hole assembly, and combinations thereof.

15. The coated drill stem assembly of claim 1, wherein the bottom hole assembly comprises one or more components chosen from stabilizers, variable-gauge stabilizers, back reamers, drill collars, flex drill collars, rotary steerable tools, roller reamers, shock subs, mud motors, logging while drilling (LWD) tools, measuring while drilling (MWD) tools, coring tools, under-reamers, hole openers, centralizers, turbines, bent housings, bent motors, drilling jars, accelerator jars, crossover subs, bumper jars, torque reduction subs, float subs, fishing tools, fishing jars, washover pipe, logging tools, survey tool subs, non-magnetic counterparts of these components, associated external connections of these components, and combinations thereof.

16. The coated drill stem assembly of claim 1, wherein the dynamic friction coefficient of the ultra-low friction coating is not lower than 50% of the static friction coefficient of the ultra-low friction coating.

17. The coated drill stem assembly of claim 16, wherein the dynamic friction coefficient of the ultra-low friction coating is not lower than about 80% of the static friction coefficient of the ultra-low friction coating.

18. The coated drill stem assembly of claim 1, wherein the dynamic friction coefficient of the ultra-low friction coating is greater than or equal to the static friction coefficient of the ultra-low friction coating.

19. The coated drill stem assembly of claim 1, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly prevents or delays the onset of drill string buckling.

20. The coated drill stem assembly of claim 1, wherein the downhole temperature during the subterraneous rotary drilling operations ranges from 20 to 400°

F.

21. The coated drill stem assembly of claim 1, 16 or 18, wherein the drilling rotary speed at the surface during the subterraneous rotary drilling operations ranges from 0 to 200 RPM.

22. The coated drill stem assembly of claim 1, 16 or 18, wherein the drilling mud pressure during the subterraneous rotary drilling operations ranges from 14 psi to 20,000 psi.

23. The coated drill stem assembly of claim 16 or 18, wherein the ultra-low friction coating provides resistance to torsional vibration instability including stick-slip vibration dysfunction of the drill string and bottom hole assembly.

24. The coated drill stem assembly of claim 1, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides a hardness greater than 400 VHN.

25. The coated drill stem assembly of claim 24, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides a hardness greater than 1500 VHN.

26. The coated drill stem assembly of claim 1, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides at least 3 times greater wear resistance than an uncoated drill stem assembly.

27. The coated drill stem assembly of claim 1, wherein the body assembly further includes hardbanding on at least a portion of the exposed outer surface to provide enhanced wear resistance and durability to the drill stem assembly.

28. The coated drill stem assembly of claim 27, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

29. The coated drill stem assembly of claim 1 or 27, wherein the body assembly further includes a buttering layer interposed between the outer surface of the body assembly and the ultra-low friction coating or hardbanding on at least a portion of the exposed outer surface to provide enhanced toughness and residual stress absorption.

30. The coated drill stem assembly of claim 29, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

31. A method for reducing friction in a coated drill stem assembly during subterraneous rotary drilling operations comprising:

providing a coated drill stem assembly comprising a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly or a coiled tubing coupled to a bottom hole assembly, and an ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly, wherein the coefficient of friction of the ultra-low friction coating is less than or equal to 0.15, and

utilizing the coated drill stem assembly in subterraneous rotary drilling operations,

wherein the ultra-low friction coating is diamond-like-carbon (DLC) and provides resistance to casing wear at least 3 times greater than an uncoated drill stem assembly.

32. The method of claim 31, wherein the subterraneous rotary drilling operations are directional including horizontal drilling or extended reach drilling (ERD).

33. The method of claim 32, further including utilizing bent motors or rotary steerable tools during horizontal drilling or extended reach drilling (ERD) to assist with directional control.

34. The method of claim 31, wherein the diamond-like-carbon (DLC) is chosen from to-C, ta-C:

H, DLCH, PLCH, GLCH, Si-DLC, N-DLC, O-DLC, B-DLC, Me-DLC, F-DLC and combinations thereof.

35. The method of claim 31, wherein the diamond-like-carbon (DLC) is applied by physical vapor deposition, chemical vapor deposition, or plasma assisted chemical vapor deposition coating techniques.

36. The method of claim 35, wherein the physical vapor deposition coating method is chosen from RF-DC plasma reactive magnetron sputtering, ion beam assisted deposition, cathodic arc deposition and pulsed laser deposition.

37. The method of claim 31, wherein the ultra-low friction coating provides a surface energy less than 1 J/m² to mitigate sticking or balling by rock cuttings during subterraneous rotary drilling operations.

38. The method of claim 37, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides a hardness greater than 400 VHN to provide for drilling in shales with water based muds and the use of spiral stabilizers.

39. The method of claim 31, wherein the water contact angle of the ultra-low friction coating is greater than 60 degrees.

40. The method of claim 31, wherein the ultra-low friction coating comprises a single ultra-low friction layer or two or more ultra-low friction layers.

41. The method of claim 40, wherein the ultra-low friction coating comprises two or more ultra-low friction layers, wherein the two or more ultra-low friction layers are of substantially the same or different ultra-low friction coatings.

42. The method of claim 40, wherein the thickness of the single ultra-low friction layer and of each layer of the two or more ultra-low friction layers ranges from 0.5 microns to 5000 microns.

43. The method of claim 40, wherein the ultra-low friction coating further comprises one or more buffer layers.

44. The method of claim 43, wherein the one or more buffer layers are interposed between the outer surface of the body assembly and the single ultra-low friction layer or the two or more ultra-low friction layers.

45. The method of claim 43, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

46. The method of claim 31, wherein the drill string comprises one or more components chosen from drill pipe, tool joints, transition pipe between the drill string and bottom hole assembly, and combinations thereof.

47. The method of claim 31, wherein the bottom hole assembly comprises one or more components chosen from stabilizers, variable-gauge stabilizers, back reamers, drill collars, flex drill collars, rotary steerable tools, roller reamers, shock subs, mud motors, logging while drilling (LWD) tools, measuring while drilling (MWD) tools, coring tools, under-reamers, hole openers, centralizers, turbines, bent housings, bent motors, drilling jars, accelerator jars, crossover subs, bumper jars, torque reduction subs, float subs, fishing tools, fishing jars, washover pipe, logging tools, survey tool subs, non-magnetic counterparts of any of these components, associated external connections of these components, and combinations thereof.

48. The method of claim 31, wherein the dynamic friction coefficient of the ultra-low friction coating is not lower than 50% of the static friction coefficient of the ultra-low friction coating.

49. The method of claim 31, wherein the dynamic friction coefficient of the ultra-low friction coating is greater than or equal to the static friction coefficient of the ultra-low friction coating.

50. The method of claim 31 wherein the downhole temperature during the subterraneous rotary drilling operations ranges from 20 to 400°

F.

51. The method of claim 31, 48 or 49, wherein the drilling rotary speed at the surface during the subterraneous rotary drilling operations ranges from 0 to 200 RPM.

52. The method of claim 31, 48 or 49, wherein the drilling mud pressure during the subterraneous rotary drilling operations ranges from 14 psi to 20,000 psi.

53. The method of claim 48 or 49, wherein the ultra-low friction coating provides resistance to torsional vibration instability including stick-slip vibration dysfunction of the drill string and bottom hole assembly.

54. The method of claim 31, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides a hardness greater than 400 VHN.

55. The method of claim 31, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides at least 3 times greater wear resistance than an uncoated drill stem assembly.

56. The method of claim 31, wherein the body assembly further includes hardbanding on at least a portion of the exposed outer surface to provide enhanced wear resistance and durability.

57. The method of claim 56, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

58. The method of claim 31 or 56, wherein the body assembly further includes a buttering layer interposed between the outer surface of the body assembly and the ultra-low friction coating or hardbanding on at least a portion of the exposed outer surface to provide enhanced toughness and residual stress absorption.

59. The method of claim 56, wherein the buttering layer comprises stainless steel or nickel base alloy.

60. The method of claim 31, wherein the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly provides substantial reduction in torque by substantially reducing friction and drag during directional or extended reach drilling facilitating drilling deeper and/or longer reach wells with existing top drive capabilities.

61. The method of claim 31, further comprising applying the ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly at the drilling rig site in the field or at a local supplier shop to apply new or refurbish worn coatings to extend the life and facilitate continued use of the assembly.

62. The method of claim 31, wherein applying the diamond-like-carbon (DLC) ultra-low friction coating includes evacuating at least a portion of the exposed outer surface of the body assembly through a means for mechanical sealing and pumping down prior to vapor deposition coating.

63. The method of claim 31, wherein the utilizing the coated drill stem assembly with coiled tubing in subterraneous rotary drilling operations provides for underbalanced drilling to reach targeted total depth without the need for drag reducing additives in the mud.

64. The method of claim 31, wherein the utilizing the coated drill stem assembly in subterraneous rotary drilling operations provides for substantial friction and drag reduction without compromising the aggressiveness of a drill bit connected to the coated drill stem assembly to transmit applied torque to rock fragmentation process.

65. The method of claim 31, wherein the corrosion resistance of the ultra-low friction coating is at least equal to the steel used for the body assembly.

66. A coated drill stem assembly for subterraneous rotary drilling operations comprising:

a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly or a coiled tubing coupled to a bottom hole assembly,

hardbanding on at least a portion of the exposed outer surface of the body assembly, and

an ultra-low friction coating on at least a portion of the hardbanding, wherein the coefficient of friction of the ultra-low friction coating is less than or equal to 0.15,

wherein the ultra-low friction coating is diamond-like-carbon (DLC) and provides resistance to casing wear at least 3 times greater than an uncoated drill stem assembly.

67. The coated drill stem assembly of claim 66, wherein the diamond-like-carbon (DLC) is chosen from to-C, ta-C:

H, DLCH, PLCH, GLCH, Si-DLC, N-DLC, O-DLC, B-DLC, Me-DLC, F-DLC and combinations thereof.

68. The coated drill stem assembly of claim 66, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

69. The coated drill stem assembly of claim 66, wherein the body assembly further includes a buttering layer interposed between the outer surface of the body assembly and the hardbanding.

70. The coated drill stem assembly of claim 69, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

71. The coated drill stem assembly of claim 66, wherein the ultra-low friction coating comprises a single ultra-low friction layer or two or more ultra-low friction layers.

72. The coated drill stem assembly of claim 71, wherein the ultra-low friction coating comprises two or more ultra-low friction layers, wherein the two or more ultra-low friction layers are of substantially the same or different ultra-low friction coatings.

73. The coated drill stem assembly of claim 71, wherein the thickness of the single ultra-low friction layer and of each layer of the two or more ultra-low friction layers ranges from 0.5 microns to 5000 microns.

74. The coated drill stem assembly of claim 71, wherein the ultra-low friction coating further comprises one or more buffer layers.

75. The coated drill stem assembly of claim 74, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

76. A method for reducing friction in a coated drill stem assembly during subterraneous rotary drilling operations comprising:

providing a drill stem assembly comprising a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly or a coiled tubing coupled to a bottom hole assembly, hardbanding on at least a portion of the exposed outer surface of the body assembly, and an ultra-low friction coating on at least a portion of the hardbanding, wherein the coefficient of friction of the ultra-low friction coating is less than or equal to 0.15, and

utilizing the coated drill stem assembly in subterraneous rotary drilling operations,

wherein the ultra-low friction coating is diamond-like-carbon (DLC) and provides resistance to casing wear at least 3 times greater than an uncoated drill stem assembly.

77. The method of claim 76, wherein the diamond-like-carbon (DLC) is chosen from to-C, ta-C:

H, DLCH, PLCH, GLCH, Si-DLC, N-DLC, O-DLC, B-DLC, Me-DLC, F-DLC and combinations thereof.

78. The method of claim 76, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

79. The method of claim 76, wherein the body assembly further includes a buttering layer interposed between the outer surface of the body assembly and the hardbanding.

80. The method of claim 79, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

81. The method of claim 76, wherein the ultra-low friction coating comprises a single ultra-low friction layer or two or more ultra-low friction layers.

82. The method of claim 81, wherein the two or more ultra-low friction layers are of substantially the same or different ultra-low friction coatings.

83. The method of claim 81, wherein the thickness of the single ultra-low friction layer and of each layer of the two or more ultra-low friction layers ranges from 0.5 microns to 5000 microns.

84. The method of claim 81, wherein the ultra-low friction coating further comprises one or more buffer layers.

85. The method of claim 84, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

86. The method of claim 76, wherein the subterraneous rotary drilling operations are directional including horizontal drilling or extended reach drilling (ERD).

87. The method of claim 86, further including utilizing bent motors or rotary steerable tools during horizontal drilling or extended reach drilling (ERD) to assist with directional control.

88. The method of claim 76, wherein the diamond-like-carbon (DLC) is applied by physical vapor deposition, chemical vapor deposition, or plasma assisted chemical vapor deposition coating techniques.

89. The method of claim 88, wherein the physical vapor deposition coating method is chosen from RF-DC plasma reactive magnetron sputtering, ion beam assisted deposition, cathodic arc deposition and pulsed laser deposition.