Coated sleeved oil and gas well production devices

• US 20110042069A1
• Filed: 02/22/2010
• Published: 02/24/2011
• 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: Ertas, Mehmet Deniz, Hecker, Michael Thomas, Ayer, Raghavan, Ozekcin, Adnan, Bangaru, Narasimha-Rao Venkata, Barry, Michael David, Biediger, Erika Ann Ooten, Yeh, Charles Shiao-Hsiung, Jin, Hyun-Woo, Bailey, Jeffrey Roberts, Bangaru, Swarupa Soma, Elks, William Curtis
• Granted Patent: US 8,286,715 B2
• Time in Patent Office: Days
• US Class Current: 166/244.1
• CPC Class Codes: E21B 17/042 Threaded
• CPC Class Codes: E21B 17/1085 Wear protectors; Blast joints; Hard facing

Abstract

Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes an oil and gas well production device including one or more bodies and one or more sleeves proximal to the outer or inner surface of the one or more bodies, and a coating on at least a portion of the inner sleeve surface, outer sleeve surface, or a combination thereof, wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt %, graphite, MoS₂, WS₂, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof. The coated sleeved oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Claims

1. A coated sleeved oil and gas well production device comprising:

one or more cylindrical bodies,

one or more sleeves proximal to the outer diameter or inner diameter of the one or more cylindrical bodies, and

a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves,

wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt. %, graphite, MoS₂, WS₂, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof.

2. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies include two or more cylindrical bodies in relative motion to each other.

3. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies include two or more cylindrical bodies that are static relative to each other.

4. The coated sleeved device of claim 1, wherein the two or more cylindrical bodies include two or more radii.

5. The coated sleeved device of claim 4, wherein the two or more cylindrical bodies include one or more cylindrical bodies substantially within one or more other cylindrical bodies.

6. The coated sleeved device of claim 4, wherein the two or more radii are of substantially the same dimensions or substantially different dimensions.

7. The coated sleeved device of claim 4, wherein the two or more cylindrical bodies are contiguous to each other.

8. The coated sleeved device of claim 4, wherein the two or more cylindrical bodies are not contiguous to each other.

9. The coated sleeved device of claim 7 or 8, wherein the two or more cylindrical bodies are coaxial or non-coaxial.

10. The coated sleeved device of claim 9, wherein bodies have substantially parallel axes.

11. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies are helical in inner surface, helical in outer surface or a combination thereof.

12. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies are solid, hollow or a combination thereof.

13. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies include at least one cylindrical body that is substantially circular, substantially elliptical, or substantially polygonal in outer cross-section, inner cross-section or inner and outer cross-section.

14. The coated sleeved device of claim 1, wherein the coefficient of friction of the coating is less than or equal to 0.15.

15. The coated sleeved device of claim 14, wherein the coefficient of friction of the coating is less than or equal to 0.10.

16. The coated sleeved device of claim 1, wherein the coating provides a hardness of greater than 400 VHN.

17. The coated sleeved device of claim 16, wherein the coating provides a hardness of greater than 1500 VHN.

18. The sleeved coated device of claim 1, wherein the coating provides at least 3 times greater wear resistance than an uncoated device.

19. The coated sleeved device of claim 1, wherein the water contact angle of the coating is greater than 60 degrees.

20. The coated sleeved device of claim 1, wherein the coating provides a surface energy less than 1 J/m².

21. The coated sleeved device of claim 20, wherein the coating provides a surface energy less than 0.1 J/m².

22. The coated sleeved device of claim 1, wherein the coating comprises a single coating layer or two or more coating layers.

23. The coated sleeved device of claim 22, wherein the two or more coating layers are of substantially the same or different coatings.

24. The coated sleeved device of claim 22, wherein the thickness of the single coating layer and of each layer of the two or more coating layers range from 0.5 microns to 5000 microns.

25. The coated sleeved device of claim 22, wherein the coating further comprises one or more buffer layers.

26. The coated sleeved device of claim 25, wherein the one or more buffer layers are interposed between the surface of the one or more cylindrical bodies and the single coating layer or the two or more coating layers.

27. The coated sleeved device of claim 25, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of the following:

silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

28. The coated sleeved device of claim 1, wherein the dynamic friction coefficient of the coating is not lower than 50% of the static friction coefficient of the coating.

29. The coated sleeved device of claim 1, wherein the dynamic friction coefficient of the coating is greater than or equal to the static friction coefficient of the coating.

30. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies further includes hardbanding on at least a portion thereof.

31. The coated sleeved device of claim 30, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

32. The coated sleeved device of claim 1 or 30 wherein the one or more cylindrical bodies further includes a buttering layer interposed between the surface of the one or more cylindrical bodies and the coating or hardbanding on at least a portion of the cylindrical bodies.

33. The coated sleeved device of claim 32, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

34. The coated sleeved device of claim 1, wherein the one or more cylindrical bodies further include threads.

35. The coated sleeved device of claim 34, wherein at least a portion of the threads are coated.

36. The coated sleeved device of claim 34 or 35, further comprising a sealing surface, wherein at least a portion of the sealing surface is coated.

37. The coated sleeved device of any one of claim 1, 2 or 3, wherein the one or more cylindrical bodies are well construction devices.

38. The coated sleeved device of claim 37, wherein the well construction devices are chosen from drill stem, casing, tubing string, wireline/braided line/multi-conductor/single conductor/slickline;

coiled tubing, vaned rotors and stators of Moyno™ and

progressive cavity pumps, expandable tubulars, expansion mandrels, centralizers, contact rings, wash pipes, shaker screens for solids control, overshot and grapple, marine risers, surface flow lines, and combinations thereof.

39. The coated sleeved device of any one of claim 1, 2 or 3, wherein the one or more cylindrical bodies are completion and production devices.

40. The coated sleeved device of claim 39, wherein the completion and production devices are chosen from plunger lifts;

completion sliding sleeve assemblies;

coiled tubing;

sucker rods;

Corods™

;

tubing string;

pumping jacks;

stuffing boxes;

packoffs and lubricators;

pistons and piston liners;

vaned rotors and stators of Moyno™ and

progressive cavity pumps;

expandable tubulars;

expansion mandrels;

control lines and conduits;

tools operated in well bores;

wireline/braided line/multi-conductor/single conductor/slickline;

centralizers;

contact rings;

perforated basepipe;

slotted basepipe;

screen basepipe for sand control;

wash pipes;

shunt tubes;

service tools used in gravel pack operations;

blast joints;

sand screens disposed within completion intervals;

Mazeflo™

completion screens;

sintered screens;

wirewrap screens;

shaker screens for solids control;

overshot and grapple;

marine risers;

surface flow lines, stimulation treatment lines, and combinations thereof.

41. The coated sleeved device of claim 1 wherein the one or more cylindrical bodies are a pin or box connection of a pipe tool joint.

42. The coated sleeved device of claim 41 wherein the one or more cylindrical bodies are configured with a proximal cylindrical cross-section that is circular in cross-section.

43. The coated sleeved device of claim 41 wherein the one or more cylindrical bodies are configured with a proximal cylindrical cross-section that is non-circular in cross-section.

44. The coated sleeved device of claim 41 wherein the pin or box connection is oriented such that the pin is facing up and the box is facing down relative to the direction of gravity.

45. The coated sleeved device of claim 41 wherein the pin or box connection is oriented such that the pin is facing down and the box is facing up relative to the direction of gravity.

46. The coated sleeved device of claim 1, wherein the one or more sleeves comprise metals, metal alloys, ceramics, cermets, polymers, carbon steels, steel alloys, stainless steels, WC based hard metals, or combinations thereof.

47. A coated sleeved oil and gas well production device comprising:

an oil and gas well production device including one or more bodies with the proviso that the one or more bodies does not include a drill bit,

one or more sleeves proximal to the outer surface or the inner surface of the one or more bodies, and

a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves,

wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated nickel-phosphorous based composite with a phosphorous content greater than 12 wt %, graphite, MoS₂, WS₂, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof.

48. The coated sleeved device of claim 47, wherein the one or more bodies include two or more bodies in relative motion to each other.

49. The coated sleeved device of claim 47, wherein the one or more bodies include two or more bodies that are static relative to each other.

50. The coated sleeved device of claim 47, wherein the one or more bodies include spheres and complex geometries.

51. The coated sleeved device of claim 50, wherein the complex geometries have at least a portion that is non-cylindrical in shape.

52. The coated sleeved device of claim 48 or 49, wherein the two or more bodies include one or more bodies substantially within one or more other bodies.

53. The coated sleeved device of claim 48 or 49, wherein the two or more bodies are contiguous to each other.

54. The coated sleeved device of claim 48 or 49, wherein the two or more bodies are not contiguous to each other.

55. The coated sleeved device of claim 48 or 49, wherein the two or more bodies are coaxial or non-coaxial.

56. The coated sleeved device of claim 47, wherein the one or more bodies are solid, hollow or a combination thereof.

57. The coated sleeved device of claim 47, wherein the one or more bodies include at least one body that is substantially circular, substantially elliptical, or substantially polygonal in outer cross-section, inner cross-section or inner and outer cross-section.

58. The coated sleeved device of claim 47, wherein the coefficient of friction of the coating is less than or equal to 0.15.

59. The coated sleeved device of claim 58, wherein the coefficient of friction of the coating is less than or equal to 0.10.

60. The coated sleeved device of claim 47, wherein the coating provides a hardness of greater than 400 VHN.

61. The coated sleeved device of claim 60, wherein the coating provides a hardness of greater than 1500 VHN.

62. The coated sleeved device of claim 47, wherein the coating provides at least 3 times greater wear resistance than an uncoated device.

63. The coated sleeved device of claim 47, wherein the water contact angle of the coating is greater than 60 degrees.

64. The coated sleeved device of claim 47, wherein the coating provides a surface energy less than 1 J/m².

65. The coated sleeved device of claim 64, wherein the coating provides a surface energy less than 0.1 J/m².

66. The coated sleeved device of claim 47, wherein the coating comprises a single coating layer or two or more coating layers.

67. The coated sleeved device of claim 66, wherein the two or more coating layers are of substantially the same or different coatings.

68. The coated sleeved device of claim 66, wherein the thickness of the single coating layer and of each layer of the two or more coating layers range from 0.5 microns to 5000 microns.

69. The coated sleeved device of claim 66, wherein the coating further comprises one or more buffer layers.

70. The coated sleeved device of claim 69, wherein the one or more buffer layers are interposed between the surface of the one or more bodies and the single coating layer or the two or more coating layers.

71. The coated sleeved device of claim 69, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of the following:

silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

72. The coated sleeved device of claim 47, wherein the dynamic friction coefficient of the coating is not lower than 50% of the static friction coefficient of the coating.

73. The coated sleeved device of claim 47, wherein the dynamic friction coefficient of the coating is greater than or equal to the static friction coefficient of the coating.

74. The coated sleeved device of claim 47, wherein the one or more bodies further includes hardbanding on at least a portion thereof.

75. The coated sleeved device of claim 74, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

76. The coated sleeved device of claim 47 or 74 wherein the one or more bodies further includes a buttering layer interposed between the surface of the one or more bodies and the coating or hardbanding on at least a portion of the bodies.

77. The coated sleeved device of claim 76, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

78. The coated sleeved device of claim 47, wherein the one or more bodies further include threads.

79. The coated sleeved device of claim 78, wherein at least a portion of the threads are coated.

80. The coated sleeved device of claim 78 or 79, further comprising a sealing surface, wherein at least a portion of the sealing surface is coated.

81. The coated sleeved device of any one of claim 47, 48 or 49, wherein the one or more bodies are well construction devices.

82. The coated sleeved device of claim 81, wherein the well construction devices are chosen from chokes, valves, valve seats, nipples, ball valves, annular isolation valves, subsurface safety valves, centrifuges, elbows, tees, couplings, blowout preventers, wear bushings, dynamic metal-to-metal seals in reciprocating and/or rotating seals assemblies, springs in safety valves, shock subs, and jars, logging tool arms, rig skidding equipment, pallets, and combinations thereof.

83. The coated sleeved device of any one of claim 47, 48 or 49, wherein the one or more bodies are completion and production devices.

84. The coated sleeved device of claim 83, wherein the completion and production devices are chosen from chokes, valves, valve seats, nipples, ball valves, inflow control devices, smart well valves, annular isolation valves, subsurface safety valves, centrifuges, gas lift and chemical injection valves, elbows, tees, couplings, blowout preventers, wear bushings, dynamic metal-to-metal seals in reciprocating and/or rotating seals assemblies, springs in safety valves, shock subs, and jars, logging tool arms, sidepockets, mandrels, packer slips, packer latches, sand probes, wellstream gauges, non-cylindrical components of sand screens, and combinations thereof.

85. The coated sleeved device of claim 47, wherein the one or more sleeves comprise metals, metal alloys, ceramics, cermets, polymers, carbon steels, steel alloys, stainless steels, WC based hard metals, or combinations thereof.

86. A method of using a coated sleeved oil and gas well production device comprising:

providing a coated oil and gas well production device including one or more cylindrical bodies with one or more sleeves proximal to the outer diameter or the inner diameter of the one or more cylindrical bodies, and a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves,

wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated nickel-phosphorous based composite with a phosphorous content greater than 12 wt %, graphite, MoS₂, WS₂, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof, and

utilizing the coated sleeved oil and gas well production device in well construction, completion, or production operations.

87. The method of claim 86, wherein the one or more cylindrical bodies include two or more cylindrical bodies in relative motion to each other.

88. The method of claim 86, wherein the one or more cylindrical bodies include two or more cylindrical bodies that are static relative to each other.

89. The method of claim 86, wherein the two or more cylindrical bodies include two or more radii.

90. The method of claim 89, wherein the two or more cylindrical bodies includes one or more cylindrical bodies substantially within one or more other cylindrical bodies.

91. The method of claim 89, wherein the two or more radii are of substantially the same dimensions or substantially different dimensions.

92. The method of claim 89, wherein the two or more cylindrical bodies are contiguous to each other.

93. The method of claim 89, wherein the two or more cylindrical bodies are not contiguous to each other.

94. The method of claim 92 or 93, wherein the two or more cylindrical bodies are coaxial or non-coaxial.

95. The method of claim 94, wherein the two or more non-coaxial cylindrical bodies have substantially parallel axes.

96. The method of claim 86, wherein the one or more cylindrical bodies are helical in inner surface, helical in outer surface or a combination thereof.

97. The method of claim 86, wherein the one or more cylindrical bodies are solid, hollow or a combination thereof.

98. The method of claim 86, wherein the one or more cylindrical bodies include at least one cylindrical body that is substantially circular, substantially elliptical, or substantially polygonal in outer cross-section, inner cross-section or inner and outer cross-section.

99. The method of claim 86, wherein the coefficient of friction of the coating is less than or equal to 0.15.

100. The method of claim 86, wherein the coating provides a hardness of greater than 400 VHN.

101. The method of claim 86, wherein the coating provides at least 3 times greater wear resistance than an uncoated device.

102. The method of claim 86, wherein the water contact angle of the coating is greater than 60 degrees.

103. The method of claim 86, wherein the coating provides a surface energy less than 1 J/m².

104. The method of claim 86, wherein the coating comprises a single coating layer or two or more coating layers.

105. The method of claim 104, wherein the two or more coating layers are of substantially the same or different coatings.

106. The method of claim 104, wherein the thickness of the single coating layer and of each layer of the two or more coating layers range from 0.5 microns to 5000 microns.

107. The method of claim 104, wherein the coating further comprises one or more buffer layers.

108. The method of claim 107, wherein the one or more buffer layers are interposed between the surface of the one or more cylindrical bodies and the single coating layer or the two or more coating layers.

109. The method of claim 107, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of the following:

silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

110. The method of claim 86, wherein the dynamic friction coefficient of the coating is not lower than 50% of the static friction coefficient of the coating.

111. The method of claim 86, wherein the dynamic friction coefficient of the coating is greater than or equal to the static friction coefficient of the coating.

112. The method of claim 86, wherein the one or more cylindrical bodies further includes hardbanding on at least a portion thereof.

113. The method of claim 112, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

114. The method of claim 86 or 112, wherein the one or more cylindrical bodies further includes a buttering layer interposed between the surface of the one or more cylindrical bodies and the coating or hardbanding on at least a portion of the cylindrical bodies.

115. The method of claim 114, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

116. The method of claim 86, wherein the one or more cylindrical bodies further include threads.

117. The method of claim 116, wherein at least a portion of the threads are coated.

118. The method of claim 116 or 117, further comprising a sealing surface, wherein at least a portion of the sealing surface is coated.

119. The method of any one of claim 86, 87, or 88, wherein the one or more cylindrical bodies are well construction devices.

120. The method of claim 119, wherein the well construction devices are chosen from drill stem, casing, tubing string, wireline/braided line/multi-conductor/single conductor/slickline;

coiled tubing, vaned rotors and stators of Moyno™ and

progressive cavity pumps, expandable tubulars, expansion mandrels, centralizers, contact rings, wash pipes, shaker screens for solids control, overshot and grapple, marine risers, surface flow lines, and combinations thereof.

121. The method of any one of claim 86, 87, or 88, wherein the one or more cylindrical bodies are completion and production devices.

122. The method of claim 121, wherein the completion and production devices are chosen from plunger lifts;

completion sliding sleeve assemblies;

coiled tubing;

sucker rods;

Corods™

;

tubing string;

pumping jacks;

stuffing boxes;

packoffs and lubricators;

pistons and piston liners;

vaned rotors and stators of Moyno™ and

progressive cavity pumps;

expandable tubulars;

expansion mandrels;

control lines and conduits;

tools operated in well bores;

wireline/braided line/multi-conductor/single conductor/slickline;

centralizers;

contact rings;

perforated basepipe;

slotted basepipe;

screen basepipe for sand control;

wash pipes;

shunt tubes;

service tools used in gravel pack operations;

blast joints;

sand screens disposed within completion intervals;

Mazeflo™

completion screens;

sintered screens;

wirewrap screens;

shaker screens for solids control;

overshot and grapple;

marine risers;

surface flow lines, stimulation treatment lines, and combinations thereof.

123. The method of claim 86, wherein the diamond-like-carbon (DLC) is applied by physical vapor deposition, chemical vapor deposition, or plasma assisted chemical vapor deposition coating techniques.

124. The method of claim 123, 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.

125. The method of claim 86 wherein the one or more cylindrical bodies are a pin or box connection of a pipe tool joint.

126. The method of claim 125 wherein the one or more cylindrical bodies are configured with a proximal cylindrical cross-section that is circular in cross-section.

127. The method of claim 125 wherein the one or more cylindrical bodies are configured with a proximal cylindrical cross-section that is non-circular in cross-section.

128. The method of claim 125 wherein the pin or box connection is oriented such that the pin is facing up and the box is facing down relative to the direction of gravity.

129. The method of claim 125 wherein the pin or box connection is oriented such that the pin is facing down and the box is facing up relative to the direction of gravity.

130. The method of claim 86, wherein the one or more sleeves comprise metals, metal alloys, ceramics, cermets, polymers, carbon steels, steel alloys, stainless steels, WC based hard metals, or combinations thereof.

131. A method of using a coated sleeved oil and gas well production device comprising:

providing a coated oil and gas well production device including one or more bodies with the proviso that the one or more bodies does not include a drill bit, with one or more sleeves proximal to the outer surface or the inner surface of the one or more bodies, and a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves,

wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated nickel-phosphorous based composite with a phosphorous content greater than 12 wt %, graphite, MoS₂, WS₂, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof, and

utilizing the coated sleeved oil and gas well production device in well construction, completion, or production operations.

132. The method of claim 131, wherein the one or more bodies include two or more bodies in relative motion to each other.

133. The method of claim 131, wherein the one or more bodies include two or more bodies that are static relative to each other.

134. The method of claim 131, wherein the one or more bodies include spheres or complex geometries.

135. The method of claim 134, wherein the complex geometries have at least a portion that is non-cylindrical in shape.

136. The method of claim 132 or 133, wherein the two or more bodies include one or more bodies substantially within one or more other bodies.

137. The method of claim 132 or 133, wherein the two or more bodies are contiguous to each other.

138. The method of claim 132 or 133, wherein the two or more bodies are not contiguous to each other.

139. The method of claim 132 or 133, wherein the two or more bodies are coaxial or non-coaxial.

140. The method of claim 131, wherein the one or more bodies are solid, hollow or a combination thereof.

141. The method of claim 131, wherein the one or more bodies include at least one body that is substantially circular, substantially elliptical, or substantially polygonal in outer cross-section, inner cross-section or inner and outer cross-section.

142. The method of claim 131, wherein the coefficient of friction of the coating is less than or equal to 0.15.

143. The method of claim 131, wherein the coating provides a hardness of greater than 400 VHN.

144. The method of claim 131, wherein the coating provides at least 3 times greater wear resistance than an uncoated device.

145. The method of claim 131, wherein the water contact angle of the coating is greater than 60 degrees.

146. The method of claim 131, wherein the coating provides a surface energy less than 1 J/m².

147. The method of claim 131, wherein the coating comprises a single coating layer or two or more coating layers.

148. The method of claim 147, wherein the two or more coating layers are of substantially the same or different coatings.

149. The method of claim 147, wherein the thickness of the single coating layer and of each layer of the two or more coating layers range from 0.5 microns to 5000 microns.

150. The method of claim 147, wherein the coating further comprises one or more buffer layers.

151. The method of claim 150, wherein the one or more buffer layers are interposed between the surface of the one or more bodies and the single coating layer or the two or more coating layers.

152. The method of claim 150, wherein the one or more buffer layers are chosen from elements, alloys, carbides, nitrides, carbo-nitrides, and oxides of the following:

silicon, titanium, chromium, tungsten, tantalum, niobium, vanadium, zirconium, or hafnium.

153. The method of claim 131, wherein the dynamic friction coefficient of the coating is not lower than 50% of the static friction coefficient of the coating.

154. The method of claim 131, wherein the dynamic friction coefficient of the coating is greater than or equal to the static friction coefficient of the coating.

155. The method of claim 131, wherein the one or more bodies further includes hardbanding on at least a portion thereof.

156. The method of claim 145, wherein the hardbanding comprises a cermet based material, a metal matrix composite or a hard metallic alloy.

157. The method of claim 131 or 155 wherein the one or more bodies further includes a buttering layer interposed between the surface of the one or more bodies and the coating or hardbanding on at least a portion of the bodies.

158. The method of claim 157, wherein the buttering layer comprises a stainless steel or a nickel based alloy.

159. The method of claim 131, wherein the one or more bodies further include threads.

160. The method of claim 159, wherein at least a portion of the threads are coated.

161. The method of claim 159 or 160, further comprising a sealing surface, wherein at least a portion of the sealing surface is coated.

162. The method of any one of claim 131, 132, or 133, wherein the one or more bodies are well construction devices.

163. The method of claim 162, wherein the well construction devices are chosen from chokes, valves, valve seats, nipples, ball valves, annular isolation valves, subsurface safety valves, centrifuges, elbows, tees, couplings, blowout preventers, wear bushings, dynamic metal-to-metal seals in reciprocating and/or rotating seals assemblies, springs in safety valves, shock subs, and jars, logging tool arms, rig skidding equipment, pallets, and combinations thereof.

164. The method of any one of claim 131, 132, or 133, wherein the one or more bodies are completion and production devices.

165. The method of claim 164, wherein the completion and production devices are chosen from chokes, valves, valve seats, nipples, ball valves, inflow control devices, smart well valves, annular isolation valves, subsurface safety valves, centrifuges, gas lift and chemical injection valves, elbows, tees, couplings, blowout preventers, wear bushings, dynamic metal-to-metal seals in reciprocating and/or rotating seals assemblies, springs in safety valves, shock subs, and jars, logging tool arms, sidepockets, mandrels, packer slips, packer latches, sand probes, wellstream gauges, non-cylindrical components of sand screens, and combinations thereof.

166. The method of claim 131, wherein the diamond-like-carbon (DLC) is applied by physical vapor deposition, chemical vapor deposition, or plasma assisted chemical vapor deposition coating techniques.

167. The method of claim 166, 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.

168. The method of claim 131, wherein the one or more sleeves comprise metals, metal alloys, ceramics, cermets, polymers, carbon steels, steel alloys, stainless steels, WC based hard metals, or combinations thereof.