초록 ▼

The subsea intervention system (SIM) includes a BOP module 10 and CT module 20. A tool positioning system 76 is used for positioning a selected subsea tool 22 stored within a rack 18 with a tool axis in line with the BOP axis, while a marinized coiled string injector 80 is moved by positioning syste

The subsea intervention system (SIM) includes a BOP module 10 and CT module 20. A tool positioning system 76 is used for positioning a selected subsea tool 22 stored within a rack 18 with a tool axis in line with the BOP axis, while a marinized coiled string injector 80 is moved by positioning system 81 to an inactive position. Power to the subsea electric motors 162 is supplied by an electrical line umbilical extending from the surface for powering the pumps 164, with the hydraulic system controlled by power control unit 198. The injector 80 preferably includes a pressure compensator roller bearing 220 and a pressure compensated drive system case 254.

대표청구항 ▼

The invention claimed is: 1. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well on coiled string and for selectively withdrawing the tool from the well through the subsea blowout prev

The invention claimed is: 1. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well on coiled string and for selectively withdrawing the tool from the well through the subsea blowout preventor and returning the selected tool to the plurality of the subsea tools, the system comprising: a subsea injector for moving the coiled string axially through the blowout preventor: one or more strippers for sealing with the axially moving string; a tool positioning system for moving the selected tool in a first linear direction substantially perpendicular to the BOP axis to a run-in position wherein the selected tool is above the blowout preventor with a tool axis substantially aligned with the BOP axis; and an injector positioning system for moving the injector from a run-in position wherein the injector is above the blowout preventor and an injector axis is substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position. 2. A subsea intervention system as defined in claim 1, further comprising: a subsea tool storage rack for storing at least some of the plurality of tools along a common plane substantially parallel to the BOP axis. 3. A subsea intervention system as defined in claim 2, wherein the tool positioning system further moves the selected tool in a second linear direction angled with respect to the first linear direction and substantially perpendicular to the BOP axis. 4. A subsea intervention system as defined in the claim 3, further comprising: a subsea tool storage rack for storing at least some of the plurality of tools along a common plane. substantially parallel to the BOP axis. 5. A subsea intervention system as defined in claim 1, wherein the tool positioning system moves the selected tool in the first linear direction with respect to a stationary tool storage rack. 6. A subsea intervention system as defined in claim 1, wherein the tool positioning system includes one or more fluid powered cylinders for moving the selected tool in the first linear direction. 7. A subsea intervention system as defined in claim 6, wherein the fluid powered cylinders are hydraulics cylinders movably responsive to hydraulic fluid pressure. 8. A subsea intervention system as defined in claim 1, wherein the tool positioning system includes one or more rack and pinion mechanisms for moving the selected tool in the first linear direction. 9. A subsea intervention system as defined in claim 1, wherein the tool positioning system moves the selected tool in a substantially vertical direction parallel to the BOP axis. 10. A subsea intervention system as defined in claim 9, wherein one or more fluid powered cylinders move the selected tool in the vertical direction. 11. A subsea intervention system as defined in claim 9, wherein one or more powered winches move the selected tool in the vertical direction. 12. A subsea intervention system as defined in claim 11, wherein each powered winch includes a chain drive mechanism for driving a chain to move the selected tool in the vertical direction. 13. A subsea intervention system as defined in claim 1, wherein the injector positioning system includes one or more fluid powered cylinders for moving the injector. 14. A subsea intervention system as defined in claim 1, wherein the injector positioning system includes a rack and pinion mechanism for moving the injector. 15. A subsea intervention system as defined in claim 1, wherein the injector positioning system includes a powered winch for moving the injector. 16. A subsea intervention system as defined in claim 1, wherein one or more linearly movable actuators move the selected tool in a substantially vertical direction. 17. A subsea intervention system as defined in claim 1, further comprising: the tool positioning system includes a plurality of actuators, a selected combination of activated actuators providing discreet positions for moving the selected tool in the first linear direction. 18. A subsea intervention system as defined in claim 17, wherein the plurality of actuators includes a plurality of fluid pressured cylinders for moving the selected tool to the first linear direction. 19. A subsea intervention system as defined in claim 17, wherein the plurality of actuators includes a plurality of fluid powered winch mechanisms for moving the selected tool in a direction substantially parallel to the BOP axis. 20. A subsea intervention system as defined in claim 1, wherein the one or more strippers move with the injector when moved to the inactive position. 21. A subsea intervention system as defined in claim 1, wherein the tool positioning system activates each of the plurality of actuators for moving the selected tool to linearly discreet positions. 22. A subsea intervention system as defined in claim 1, wherein the coiled string is stored on a subsea reel. 23. A subsea intervention system as defined in claim 22, wherein the reel is lowered subsea with the subsea injector. 24. A subsea intervention system as defined in claim 22, wherein a reel center of gravity is lower than a top of the injector. 25. A subsea intervention system as defined in claim 1, wherein the coiled string is one of a coiled tubing string and a coiled wireline. 26. A subsea intervention system as defined in claim 1, wherein the coiled string is a coiled tubing string. 27. A subsea intervention system as defined in claim 1, wherein each of the plurality of tools is stored in a substantially cylindrical tube with an open top. 28. A subsea intervention system as defined in claim 1, further comprising: a lower gate valve; an upper gate valve; and an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 29. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving a coiled string through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; one or more subsea motors electrically powered by an electrical umbilical extending to the surface; and one or fluid pumps powered by the one or more motors, the pumps powering at least one of the tool positioning system and the injector positioning system. 30. A subsea intervention system as defined in claim 29, wherein the subsea intervention system is powered by at least one of the electrical umbilical extending to the surface and a subsea ROV. 31. A subsea intervention system as defined in claim 29, further comprising: the plurality of tools are arranged within one or more planes each substantially parallel to the BOP axis. 32. A subsea intervention system as defined in claim 29, further comprising: one or more strippers for sealing with the axially moving string. 33. A subsea intervention system as defined in claim 29, wherein the coiled string is a coiled tubing string. 34. A subsea intervention system as defined in claim 29, wherein the coil string is stored on a subsea reel. 35. A subsea intervention system as defined in claim 34, wherein a reel center of gravity is lower than a top of the injector. 36. A subsea intervention system as defined in claim 31, further comprising: a lower gate valve; an upper gate valve; and an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 37. A subsea intervention system as defined in claim 29, wherein each of the plurality of tools is stored in a substantially cylindrical tube with an open top. 38. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving a coiled string through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and a BOP structural frame housing the blowout preventor, the structural frame substantially decoupling forces transmitted through the blowout preventor. 39. A subsea intervention system as defined in claim 38, wherein the structural frame sustains at least four times the forces transmitted through the blowout preventor. 40. A subsea intervention system as defined in claim 38, further comprising: one or more strippers for sealing with the axially moving string. 41. A subsea intervention system as defined in claim 38, wherein the coiled string is a coiled tubing string. 42. A subsea intervention system as defined in claim 38, wherein the coiled string is stored on a subsea reel. 43. A subsea intervention system as defined in claim 38, wherein a reel center of gravity is lower than a top of the injector. 44. A subsea intervention system as defined in claim 38, further comprising: a lower gate valve; an upper gate valve; and an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 45. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving the selected tool through the blowout preventor; a lower gate valve; a tool latching device to latch the selected tool to a coiled string; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and an axial length of each of the plurality of tools is no greater than an axial spacing between the lower gate valve and the tool latching device. 46. A subsea intervention system as defined in claim 45, further comprising: one or more strippers for sealing with the axially moving string. 47. A subsea intervention system as defined in claim 45, wherein the coiled string is a coiled tubing string. 48. A subsea intervention system as defined in claim 45, wherein the coiled string is stored on a subsea reel. 49. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving the selected tool through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and a subsea coiled string reel with a reel center of gravity lower than a top of the injector. 50. A subsea intervention system as defined in claim 49, further comprising: one or more strippers for sealing with the axially moving string. 51. A subsea intervention system as defined in claim 49, wherein the coiled string is a coiled tubing string. 52. A subsea intervention system as defined in claim 49, wherein the coiled string is stored on a subsea reel. 53. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving the selected tool through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and a circulation system for flushing the selected tool with fluid while substantially aligned with the well. 54. A subsea intervention system as defined in claim 53, further comprising: one or more strippers for sealing with the axially moving string. 55. A subsea intervention system as defined in claim 53, wherein the coiled string is a coiled tubing string. 56. A subsea intervention system as defined in claim 53, wherein the coiled string is stored on a subsea reel. 57. A subsea intervention system as defined in claim 53, further comprising: a lower gate valve; an upper gate valve; and an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 58. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving the selected tool through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; a pivoting mechanism for moving the injector from a run-in position to allow the selected tool to be positioned above the blowout preventor. 59. A subsea intervention system as defined in claim 58, further comprising: one or more strippers for sealing with the axially moving string. 60. A subsea intervention system as defined in claim 58, wherein the coiled string is a coiled tubing string. 61. A subsea intervention system as defined in claim 58, wherein the coiled string is stored on a subsea reel. 62. A subsea intervention system for lowering a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and for selectively withdrawing the tool from the well, through the subsea blowout preventor and returning the selected tool to the plurality of stored subsea tools, further comprising: a subsea injector for moving the selected tool through the blowout preventor; a tool positioning system for moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; an injector positioning system for moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and a Y-mechanism for placing the injector in parallel with the selected tool when in the run-in position. 63. A subsea intervention system as defined in claim 62, further comprising: one or more strippers for sealing with the axially moving string. 64. A subsea intervention system as defined in claim 62, wherein the coiled string is stored on a subsea reel. 65. A subsea intervention system as defined in claim 62, wherein the coiled string is a coiled tubing string. 66. A method of operating subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well on coiled string and to selectively withdraw the tool from the well through the subsea blowout preventor and return the selected tool to the plurality of the subsea tools, the method comprising: providing a subsea injector for moving the coiled string axially through the blowout preventor; providing one or more strippers for sealing with the axially moving string; moving the selected tool in a first linear direction substantially perpendicular to the BOP axis to a run-in position wherein the selected tool is above the blowout preventor with a tool axis substantially aligned with the BOP axis; and moving the injector from a run-in position wherein the injector is above the blowout preventor and an injector axis is substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position. 67. A method as defined in claim 66, further comprising: providing a subsea tool storage rack for storing at least some of the plurality of tools along a common plane substantially parallel to the BOP axis. 68. A method as defined in claim 67, wherein the selected tool is moved in a second linear direction angled with respect to the first linear direction and substantially perpendicular to the BOP axis. 69. A method as defined in the claim 68, further comprising: providing a subsea tool storage rack for storing at least some of the plurality of tools along a common plane substantially parallel to the BOP axis. 70. A method as defined in claim 66, wherein the selected tool is moved in the first linear direction with respect to a stationary tool storage rack. 71. A method as defined in claim 66, wherein one or more fluid powered cylinders move the selected tool in the first linear direction. 72. A method as defined in claim 66, wherein one or more rack and pinion mechanisms move the selected tool in the first linear direction. 73. A method as defined in claim 66, wherein the selected tool is moved in a substantially vertical direction parallel to the BOP axis. 74. A method as defined in claim 73, wherein one or more fluid powered cylinders move the selected tool in the vertical direction. 75. A subsea intervention system as defined in claim 66, wherein one or more powered winches move the selected tool in the vertical direction. 76. A method as defined in claim 75, wherein a chain drive mechanism drives a chain to move the selected tool in the vertical direction. 77. A method as defined in claim 73, wherein one or more fluid powered cylinders move the selected tool in the vertical direction. 78. A method as defined in claim 66, wherein one or more fluid powered cylinders move the injector. 79. A method as defined in claim 66, wherein a rack and pinion mechanism moves the injector. 80. A method as defined in claim 66, wherein a powered winch moves the injector. 81. A method as defined in claim 66, further comprising: providing a plurality of actuators, a selected combination of activated actuators providing discreet positions for moving the selected tool in the first linear direction. 82. A method as defined in claim 81, wherein a plurality of fluid powered cylinders move the selected tool to the first linear direction. 83. A method as defined in claim 81, wherein a plurality of fluid powered winch mechanisms move the selected tool in a direction substantially parallel to the BOP axis. 84. A method as defined in claim 81, wherein one or more strippers move with the injector when moved to the inactive position. 85. A method as defined in claim 81, wherein the plurality of actuators are activated to move the selected tool to linearly discreet positions. 86. A method as defined in claim 66, wherein the coiled string is stored on a subsea reel. 87. A method as defined in claim 66, wherein the reel is lowered subsea with the subsea injector. 88. A method as defined in claim 66, wherein a reel center of gravity is lower than a top of the injector. 89. A method as defined in claim 66, wherein the coiled string is one of the coiled tubing string and the coiled wireline. 90. A method as defined in claim 66, wherein the coiled string is a coiled tubing string. 91. A method as defined in claim 66, wherein each of the plurality of tools are stored in a substantially cylindrical tube with an open top. 92. A method as defined in claim 66, further comprising: providing a lower gate valve; providing an upper gate valve; and controlling an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 93. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the B0P axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; electrically powering one or more subsea motors by an electrical umbilical extending to the surface; and providing the motors to drive one or more or fluid pumps, the pumps powering an intervention hydraulic system. 94. A methods as defined in claim 93, wherein the subsea intervention system is powered by at least one of the electrical umbilical extending to the surface and a subsea ROV. 95. A subsea intervention system as defined in claim 93, further comprising: storing a plurality at tools within one or more planes each substantially parallel to the BOP axis. 96. A method as defined in claim 93, further comprising: providing one or more strippers for sealing with the axially moving string. 97. A method as defined in claim 93, wherein the coiled string is a coiled tubing string. 98. A method as defined in claim 93, wherein the coiled string is stored on a subsea reel. 99. A method as defined in claim 98, wherein a reel center of gravity is lower than a top of the injector. 100. A method as defined in claim 93, further comprising: providing a lower gate valve; providing an upper gate valve; and controlling the axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 101. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and housing the blowout preventor within a BOP structural frame, thereby substantially decoupling forces transmitted through the blowout preventor. 102. A method as defined in claim 101, wherein the structural frame sustains at least four times the forces transmitted through the blowout preventor. 103. A method as defined in claim 101, further comprising: providing one or more strippers for sealing with the axially moving string. 104. A method as defined in claim 101, wherein the coiled string is a coiled tubing string. 105. A method as defined in claim 101, wherein the coiled string is stored on a subsea reel. 106. A method as defined in claim 101, wherein a reel center of gravity is lower than a top of the injector. 107. A method as defined in claim 101, further comprising: providing a lower gate valve; providing an upper gate valve; and controlling an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 108. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and controlling an axial length of each of the plurality of tools to be no greater than an axial spacing between a gate valve and a latch. 109. A method as defined in claim 108, further comprising: providing one or more strippers for sealing with the axially moving string. 110. A method as defined in claim 108, wherein the coiled string is a coiled tubing string. 111. A method as defined in claim 108, wherein the coiled string is stored on a subsea reel. 112. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and positioning a subsea coiled string reel below a top of the injector. 113. A method as defined in claim 112, further comprising: providing one or more strippers for sealing with the axially moving string. 114. A method as defined in claim 112, wherein the coiled string is a coiled tubing string. 115. A method as defined in claim 112, wherein the coiled string is stored on a subsea reel. 116. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and providing a circulation system for flushing the selected tool with fluid while substantially aligned with the well. 117. A method as defined in claim 116, further comprising: providing one or more strippers for sealing with the axially moving string. 118. A method as defined in claim 116, wherein the coiled string is a coiled tubing string. 119. A method as defined in claim 116, wherein the coiled string is stored on a subsea reel. 120. A method as defined in claim 116, wherein a reel center of gravity is lower than a top of the injector. 121. A method as defined in claim 116, further comprising: providing a lower gate valve; providing an upper gate valve; and controlling an axial length at each of the plurality of the tools is no greater than an axial spacing between the lower gate valve and the upper gate valve. 122. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; providing a pivoting mechanism for moving the injector from a run-in position to allow the selected tool to be positioned above the blowout preventor. 123. A method as defined in claim 122, further comprising: providing one or more strippers for sealing with the axially moving string. 124. A method as defined in claim 122, wherein the coiled string is a coiled tubing string. 125. A method as defined in claim 122, wherein the coiled string is stored on a subsea reel. 126. A method of operating a subsea intervention system to lower a selected tool from a plurality of stored subsea tools through a subsea blowout preventor having a BOP axis and into a well, and to selectively withdraw the tool from the well, through the subsea blowout preventor and return the selected tool to the plurality of stored subsea tools, the method comprising: providing a subsea injector for moving the selected tool through the blowout preventor; moving the selected tool from a storage position to a run-in position above the blowout preventor with a tool axis substantially aligned with the BOP axis; moving the injector from the run-in position wherein the injector is above the blowout preventor with an injector axis substantially aligned with the BOP axis, to an inactive position for allowing the selected tool to occupy at least a portion of the BOP axis occupied by the injector when in the run-in position; and providing a Y-mechanism for placing the injector in parallel with the selected tool when in the run-in position. 127. A method as defined in claim 126, further comprising: providing one or more strippers for sealing with the axially moving string. 128. A method as defined in claim 126, wherein the coiled string is a coiled tubing string. 129. A method as defined in claim 126, wherein the coiled string is stored on a subsea reel.