A marine drilling platform and automated tubing handling system

Abstract

This invention belongs to the field of oil drilling and production technology, specifically disclosing an offshore drilling platform and an automated tubing handling system. The platform includes a cantilever beam base, which consists of a lower cantilever beam base and a drilling rig. The drilling rig is slidably connected to the top of the lower cantilever beam base, and the lower cantilever beam base is slidably connected to the top of the platform. A winch, a narrow derrick, a driller's cab, and a crane are fixedly installed on the top of the drilling rig. This invention employs a specially designed narrow derrick, which occupies less drilling rig area, requires fewer transport modules, and is lightweight. Furthermore, the drill pipe erector is not placed on the drilling rig, and there is no high-altitude pipe laying equipment, lowering the overall structural center of gravity, reducing the windward area, and improving wind resistance stability. Simultaneously, it allows for independent drill pipe erector establishment, saving drilling preparation time and enabling earlier drilling or drilling while erecting the erector. Additionally, the equipment is installed and maintained at a low position, significantly reducing the difficulty of installation and maintenance.

Description

Technical Field

[0001] This invention belongs to the field of oil drilling and production technology, and specifically relates to an offshore drilling platform and an automated tubing handling system. Background Technology

[0002] Conventional offshore drilling platforms typically employ a K-type or fully enclosed tower-type derrick structure, with a height of approximately 40-50m. All risers are stored within the second-level platform of the derrick. If an automated pipe handling system is configured, there are generally pipe handling robots on the second-level platform and on the drilling surface, or a column-type pipe handling machine of the same height as the second-level platform is used for coordinated gripping and pipe handling, resulting in a relatively high overall center of gravity for the drilling rig structure.

[0003] According to API Spec 4F, the wind load requirements for offshore drilling structures are greater than those on land under various operating conditions. For example, the expected operating condition is as high as 47.8 m / s, which is much higher than the 38.6 m / s for land drilling rigs. With the drilling rig structure having a high center of gravity and a large windward area, higher requirements are placed on the platform's wind resistance stability and structural strength. At the same time, when the top drive moves the drill pipe, the drill pipe will sway during the movement, affecting the connection between the drill pipe and the drill pipe inside the wellhead of the drilling platform, and thus affecting the extraction of subsea drill pipe in the wellhead. To address these issues, how to design an offshore drilling platform and an automated tubing handling system has become a problem that we need to solve. Summary of the Invention

[0004] The purpose of this invention is to address the shortcomings of existing technologies by proposing a marine drilling platform and an automated tubing handling system.

[0005] To achieve the above objectives, the present invention provides an offshore drilling platform and an automated tubing handling system, including a platform and a cantilever beam base. The cantilever beam base consists of a lower layer of the cantilever beam base and a drilling platform, and the drilling platform is slidably connected to the top of the lower layer of the cantilever beam base. The lower layer of the cantilever beam base is slidably connected to the top of the platform. A winch, a narrow derrick, an iron driller, a driller's cabin, and a crane are fixedly installed on the top of the drilling platform.

[0006] In the above technical solution, a storage area is further provided on the top of the lower layer of the cantilever beam base, and a wellhead is fixedly installed inside the storage area. The wellhead is located on the side of the narrow derrick away from the winch, and a slide rail is fixedly installed on the side of the narrow derrick away from the winch.

[0007] An automated pipe handling system for an offshore drilling platform includes a handling component. The handling component includes a lifting manipulator fixedly installed on the top of the lower layer of a cantilever beam base, a pipe laying machine track, an upper clamping manipulator, and a cantilever crane fixedly installed on the top of a narrow derrick. The number of pipe laying machine tracks is set to two sets, and a horizontal pipe laying machine is slidably connected to the top of each set of pipe laying machine tracks.

[0008] In the above technical solution, a traveling block is provided on one side of the narrow derrick, a top drive is fixedly connected to one end of the traveling block, and the end of the traveling block away from the top drive is fixedly connected to the winch after being limited and guided by the cantilever crane. A drill pipe is provided at the bottom of the top drive.

[0009] In the above technical solution, a connecting rod is fixedly installed on one side of the top drive, and two connecting rods are hinged to the outer wall of the connecting rod. A sliding sleeve is hinged to the end of the two connecting rods away from the connecting rod, and the sliding sleeve is slidably connected to the outer wall of the slide rail.

[0010] In the above technical solution, the outer wall of the sliding sleeve is further hinged with a first electric push rod, and the end of the first electric push rod away from the sliding sleeve is rotatably connected to a locking member. The locking member is threadedly connected to the inside of the sliding sleeve and abuts against the outer wall of the slide rail.

[0011] In the above technical solution, the narrow derrick is further provided with a straightening manipulator inside. The straightening manipulator includes a mounting base fixedly installed on the bottom crossbeam of the narrow derrick. A support arm and a second electric push rod are hinged to the outer wall of the mounting base. The end of the second electric push rod away from the mounting base is hinged to the outer wall of the support arm. A third electric push rod is fixedly installed inside the support arm. A connecting member is slidably connected inside the support arm. The third electric push rod is hinged inside the connecting member.

[0012] In the above technical solution, further, a connecting plate is fixedly connected to the end of the connector away from the support arm, a conical rotating sleeve is rotatably connected to the top of the connecting plate, a fourth electric push rod is hinged to both sides of the connecting plate, an arc-shaped hinge rod is hinged to the end of each of the two fourth electric push rods away from the connecting plate, an arc-shaped rotating sleeve is rotatably connected to the top of each of the two arc-shaped hinge rods, the two arc-shaped hinge rods are respectively hinged to the outer walls of both sides of the connecting plate, and the drill rod is inserted between the conical rotating sleeve and the two arc-shaped rotating sleeves.

[0013] Compared with existing technologies:

[0014] This invention employs a specially designed narrow derrick, which occupies a small area on the drilling platform, requires fewer transport modules, and is lightweight. Furthermore, the drill pipe erector is not placed on the drilling platform, and there is no high-altitude pipe laying equipment, thus lowering the center of gravity of the overall structure, reducing the windward area, and improving wind resistance stability. At the same time, the string handling system can independently establish the drill pipe erector, saving drilling preparation time, so as to start drilling earlier or drill while establishing the erector. In addition, all automated equipment is installed and maintained at a low position, greatly reducing the difficulty of installation and maintenance. Attached Figure Description

[0015] Figure 1 This is an elevation view of the offshore drilling platform and automated tubing handling system proposed in this invention;

[0016] Figure 2 This is a plan view of the offshore drilling platform and automated tubing handling system proposed in this invention;

[0017] Figure 3 This is a schematic diagram of the top drive extension state structure proposed in this invention;

[0018] Figure 4 This is a schematic diagram of the straightening robot structure proposed in this invention;

[0019] Figure 5 The present invention proposes Figure 4 Enlarged view of the structure of part A.

[0020] In the diagram: 1. Platform; 101. Wellhead; 102. Storage area; 2. Cantilever beam base; 201. Lower layer of cantilever beam base; 202. Drilling platform; 3. Drilling winch; 4. Narrow derrick; 401. Slide rail; 5. Cantilever crane; 6. Traveling trolley; 7. Top drive; 701. Connecting rod; 702. Connecting rod; 703. Sliding sleeve; 704. First electric push rod; 705. Locking component; 8. Lifting robot; 9. Horizontal pipe laying machine; 901. Pipe laying machine track; 10. Iron drill; 11. Straightening robot; 1101. Mounting base; 1102. Support arm; 1103. Second electric push rod; 1104. Third electric push rod; 1105. Connecting component; 1106. Connecting plate; 1107. Conical rotating sleeve; 1108. Fourth electric push rod; 1109. Arc-shaped hinge rod; 1110. Arc-shaped rotating sleeve; 12. Upper locking robot; 13. Driller's cabin; 14. Crane; 100. Drill rod. Detailed Implementation

[0021] To better understand the above-mentioned objectives, features, and advantages of the present invention, the present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0022] like Figures 1 to 2The offshore drilling platform and automated tubing handling system shown include a platform 1 and a cantilever beam base 2. The cantilever beam base 2 consists of a lower cantilever beam base 201 and a drilling platform 202. The drilling platform 202 is slidably connected to the top of the lower cantilever beam base 201, and the lower cantilever beam base 201 is slidably connected to the top of the platform 1. A winch 3, a narrow derrick 4, an iron driller 10, a driller's cabin 13, and a crane 14 are fixedly installed on the top of the drilling platform 202. A storage area 102 is provided on the top of the lower cantilever beam base 201. A wellhead 101 is fixedly installed inside the storage area 102. The wellhead 101 is located on the side of the narrow derrick 4 away from the winch 3. A slide rail 401 is fixedly installed on the side of the narrow derrick 4 away from the winch 3.

[0023] Platform 1 is a ship structure on which drilling-related equipment such as solids control systems, power systems, and helicopter platforms are installed.

[0024] The cantilever beam base lower layer 201 and the drilling platform 202 are slidably connected. The cantilever beam base lower layer 201 and the platform 1 are slidably connected, so that the drilling platform 202 can slide relative to the cantilever beam base lower layer 201 in the Y-axis direction and the cantilever beam base lower layer 201 can slide relative to the platform 1 in the X-axis direction. This allows the cantilever beam base lower layer 201 and the drilling platform 202 to move after clamping and fixing the drill rod 100 uprights, aligning the drill rod 100 uprights with the tops of other wellheads 101, and connecting and fixing the drill rod 100 uprights inside other wellheads 101. This enables cluster well operations within a certain area (X is the longitudinal direction of platform 1, Y is the transverse direction of platform 1), improving the applicability. Furthermore, when performing cluster well operations, the storage area 102 can move with the wellheads 101 without the need to move or disassemble the equipment in the storage area 102 separately.

[0025] The wellhead 101, located outside the narrow derrick 4, can improve the driller's field of vision and eliminate the problem of the narrow derrick 4 obstructing the wellbore view.

[0026] Among them, the narrow derrick 4 has a three-section structure, with each section not exceeding 12m, in order to meet the land transportation requirements;

[0027] Among them, the iron drill 10 is used to connect and disconnect the drill pipe 100 joint at the wellhead 101;

[0028] Among them, the driller's cabin 13 is a standard dual-seat driller's cabin for automated drilling rigs, used to coordinate and control the entire drilling module. The chief driller is mainly responsible for operating equipment related to drilling processes, while the assistant driller is mainly responsible for managing the automated tubing handling system and tubing storage yard.

[0029] like Figures 1 to 5An automated pipe handling system for an offshore drilling platform is shown, comprising a handling component. The handling component includes a lifting manipulator 8 fixedly installed on the top of the lower layer 201 of the cantilever beam base, a pipe laying machine track 901, an upper clamping manipulator 12, and a cantilever crane 5 fixedly installed on the top of the narrow derrick 4. The number of pipe laying machine tracks 901 is set to two sets, and a horizontal pipe laying machine 9 is slidably connected to the top of each set of pipe laying machine tracks 901. A traveling block 6 is provided on one side of the narrow derrick 4. A top drive 7 is fixedly connected to one end of the traveling block 6. The end of the traveling block 6 away from the top drive 7 is fixedly connected to the winch 3 after being limited and guided by the cantilever crane 5. A drill pipe 100 is provided at the bottom of the top drive 7.

[0030] Among them, the cantilever crane 5 is a fixed pulley group of the traveling car 6, which is used to assist the winch 3 in pulling the traveling car 6 up and down through the cantilever crane 5;

[0031] Among them, the lifting robot 8 is composed of lifting and pipe gripping mechanisms, and is mainly used to lift the 100 drill rods in the horizontal position to a vertical position. When the lifting robot 8 is retracted, it is located inside the two sets of pipe laying machine tracks 901, avoiding the movement trajectory of the horizontal pipe laying machine 9, and does not affect the normal use of the horizontal pipe laying machine 9.

[0032] Among them, the pipe laying machine track 901 is arranged along the Y direction of the platform 1, and the horizontal pipe laying machine 9 can slide along the two sets of pipe laying machine tracks 901 laid on the lower layer 201 of the cantilever beam base.

[0033] The upper locking manipulator 12 consists of a rotating locking clamp and a locking and snapping clamp. It is mainly used to connect two drill rods 100 placed horizontally on the ground at the top of the lower layer 201 of the cantilever beam base to form a support (a structure composed of multiple drill rods 100) or to disassemble the support into a single drill rod 100. This achieves the effect of combining drill rods 100 into a support or disassembling a support into drill rods 100. Both are combined or disassembled horizontally on the ground, enabling low-position work, facilitating subsequent maintenance, and avoiding instability of the drilling platform's center of gravity and excessive influence from sea winds caused by combining drill rods 100 or disassembling support at a high position.

[0034] A connecting rod 701 is fixedly installed on one side of the top drive 7. Two connecting rods 702 are hinged to the outer wall of the connecting rod 701. A sliding sleeve 703 is hinged to the end of the two connecting rods 702 away from the connecting rod 701. The sliding sleeve 703 is slidably connected to the outer wall of the slide rail 401. A first electric push rod 704 is hinged to the outer wall of the sliding sleeve 703. A locking member 705 is rotatably connected to the end of the first electric push rod 704 away from the sliding sleeve 703. The locking member 705 is threadedly connected to the inside of the sliding sleeve 703 and abuts against the outer wall of the slide rail 401.

[0035] Among them, by setting the top drive 7 structure, when it is lifted and lowered by the traveling trolley 6, it can move a certain distance along the platform 1X direction as needed, so as to transport the drill rod 100.

[0036] Specifically, when it is necessary to transport the drill rods 100 vertically mounted on the lifting manipulator 8, the winch 3 can be activated, causing the winch 3 to pull the top drive 7 upward via the cantilever crane 5 and the traveling crane 6. During the upward movement of the top drive 7, the top drive 7 will pull the sliding sleeve 703 up and down along the outer wall of the slide rail 401 via the connecting rod 701 and the connecting rod 702. When the sliding sleeve 703 rises to a specific position on the slide rail 401, the first electric push rod 704 will trigger the locking member 705 to rotate, causing the locking member 705 to rotate along the threaded hole of the sliding sleeve 703 and clamp it in place. The outer wall of the slide rail 401 limits and fixes the position of the slide sleeve 703 on the slide rail 401. At this time, the top drive 7 cannot drive the slide sleeve 703 to move through the connecting rod 701 and the connecting rod 702. As the traveling carriage 6 continues to pull the top drive 7 to rise, the top drive 7 begins to pull the connecting rod 702 through the connecting rod 701 to rotate around the hinge of the slide sleeve 703, so that the top drive 7 begins to move away from the slide sleeve 703, and then the top drive 7 can move to the top of the drill rod 100 root fixed by the lifting manipulator 8 to connect and fix the drill rod 100 root.

[0037] Furthermore, after the drill pipe 100 is fixed in place, the lifting manipulator 8 will release the drill pipe 100 and reset. Meanwhile, the winch 3 will lower the top drive 7 via the overhead crane 5 and traveling block 6, allowing the top drive 7 to descend under its own weight and that of the drill pipe 100 until it reaches the top of the wellhead 101, driven by the connecting rod 701 and rotating the connecting rod 702. At this point, the first electric push rod 704 retracts, pulling the locking element 705 to rotate and reset, stopping the restriction on the slide rail 401 and the sliding sleeve 703, allowing the top drive 7 to drive the drill pipe 100. The drill pipe 100 is lowered and connected to the drill pipe 100 inside the wellhead 101, improving the connection success rate and efficiency of the drill pipe 100, so as to extract underwater oil, gas and other products from the drill pipe 100. After the drill pipe 100 on the top drive 7 is connected to the drill pipe 100 inside the wellhead 101, the top drive 7 will stop connecting the drill pipe 100 and allow the top drive 7 to rise and reset under the pull of the winch 3 through the cantilever crane 5 and the traveling block 6. At this time, the process ends. If it is necessary to continue to transport the drill pipe 100 on the lifting manipulator 8, the above steps are repeated.

[0038] The narrow derrick 4 is equipped with a straightening manipulator 11. The straightening manipulator 11 includes a mounting base 1101 fixedly mounted on the bottom crossbeam of the narrow derrick 4. A support arm 1102 and a second electric push rod 1103 are hinged to the outer wall of the mounting base 1101. The end of the second electric push rod 1103 away from the mounting base 1101 is hinged to the outer wall of the support arm 1102. A third electric push rod 1104 is fixedly mounted inside the support arm 1102. A connector 1105 is slidably connected inside the support arm 1102. The third electric push rod 1104 is hinged inside the connector 1105. 5. A connecting plate 1106 is fixedly connected to one end away from the support arm 1102. A conical rotating sleeve 1107 is rotatably connected to the top of the connecting plate 1106. A fourth electric push rod 1108 is hinged to both sides of the connecting plate 1106. An arc-shaped hinge rod 1109 is hinged to one end of each of the two fourth electric push rods 1108 away from the connecting plate 1106. An arc-shaped rotating sleeve 1110 is rotatably connected to the top of each of the two arc-shaped hinge rods 1109. The two arc-shaped hinge rods 1109 are respectively hinged to the outer walls of both sides of the connecting plate 1106. The drill rod 100 is inserted between the conical rotating sleeve 1107 and the two arc-shaped rotating sleeves 1110.

[0039] Among them, the setting of the upper clamping manipulator 12 structure can stabilize the drill rod 100, improve the efficiency of the drill rod 100 being connected to the iron driller 10 at the wellhead 101 position, and prevent the drill rod 100 from swinging continuously after being transported by the top drive 7, which would affect the connection of the male and female joints 110 and the success rate of entering the wellhead 101.

[0040] Specifically, after the top drive 7 moves the drill pipe 100 upright to the top of the wellhead 101, the fourth electric push rod 1108 can be extended to push the arc-shaped hinge rod 1109 to rotate. This causes the arc-shaped hinge rod 1109 to rotate around the hinge of the connecting plate 1106, allowing it to push the arc-shaped rotating sleeve 1110 to clamp and limit the drill pipe 100 upright. The drill pipe 100 upright is then limited between the conical rotating sleeve 1107 and the two arc-shaped rotating sleeves 1110, guiding and limiting the descent of the drill pipe 100 upright, thus improving the success rate of the drill pipe 100 upright's descent and docking, as well as its insertion into the wellhead 101.

[0041] Furthermore, when it is necessary to limit and fix drill pipe 100 supports of different diameters, the third electric push rod 1104 can be controlled to pull or push the connecting piece 1105 along the direction of the support arm 1102. This causes the connecting piece 1105 to move through the connecting plate 1106 and its components, thereby changing the distance between the central axis of the drill pipe 100 supports and the central axis of the wellhead 101 after the conical rotating sleeve 1107 and the arc-shaped rotating sleeve 1110 limit and fix the drill pipe 100 supports. This allows the central axes of drill pipe 100 supports of different diameters to coincide with the central axis of the wellhead 101, improving the applicability. By limiting and fixing drill pipe 100 supports of different diameters and adjusting the position of the fixed drill pipe 100 supports' central axis, the system can adapt to the diameter and central axis of drill pipe 100 supports inside other wellheads 101 in cluster well operations, thereby improving the efficiency and applicability of cluster well operations.

[0042] Its working principle is described as follows:

[0043] The process of establishing the drill rod 100: First, the staff inside the driller's cabin 13 start the horizontal pipe laying machine 9 to pick up the drill rod 100 in the storage area 102 and transport it to the upper hook manipulator 12. The upper hook manipulator 12 connects two drill rods 100 to form a root. Then, the horizontal pipe laying machine 9 transports the connected drill rod 100 root to the designated area in the storage area 102 for storage. It should be noted that if there are not enough drill rods 100 in the storage area 102, the crane 14 can be used to grab the drill rods 100 in the storage area of ​​the platform 1 and supplement them to the designated location in the storage area 102.

[0044] Drilling process: The horizontal pipe laying machine 9 delivers the connected drill rod 100 upright to the lifting manipulator 8, which grasps the drill rod 100 upright and lifts it to a vertical position. Then, the winch 3 drives the top drive 7 to move through the cantilever crane 5 and the traveling crane 6, so that the top drive 7 structure extends and connects and fixes 110. Subsequently, the lifting manipulator 8 releases the drill rod 100 and withdraws from the high position. The top drive 7 structure retracts back above the wellhead 101 and works with the straightening manipulator 11 to stabilize and guide the drill rod 100 joint to align with the wellhead 101, so that the driller 10 can complete the connection between the drill rod 100 upright and the drill rod 100 upright inside the wellhead 101. After the 110 upright is connected to the drill rod 100 upright inside the wellhead 101, the top drive 7 stops connecting and fixing the drill rod 100 upright and moves up to the reset position without load, ready for the next cycle.

[0045] The tripping process is the reverse of the tripping process, and will not be described in detail here.

[0046] This invention employs a specially designed narrow derrick 4, which occupies a small area on the drilling platform 202, requires fewer transport modules, and is lightweight. Furthermore, the drill pipes 100 are not placed on the drilling platform 202, and there is no high-altitude pipe-laying equipment. This lowers the overall structural center of gravity, reduces the windward area, and improves wind resistance stability, thereby reducing the wind load on the drilling derrick under expected storm conditions. The simplified derrick structure, without a second platform or high-altitude pipe-laying equipment, allows for a significantly lighter derrick design by drastically reducing the area of ​​wind-exposed components. This results in a weight reduction of over 40% compared to conventional derricks, reducing the overall load on the platform and addressing the issue of wind loads on offshore platforms being much greater than on land, and the resulting bulky structures. Simultaneously, the accompanying pipe handling system fully utilizes the deck space below the cantilever beam base 201, enabling independent installation of the drill pipes 100 on the deck surface without occupying the wellhead 101, saving drilling preparation time and allowing for earlier drilling or drilling while the pipes are being installed. Furthermore, all automated equipment is installed and maintained at a low level, significantly reducing the difficulty of installation and maintenance.

[0047] The foregoing has shown and described the basic principles, main features, and advantages of the present invention. Those skilled in the art should understand that the present invention is not limited to the above embodiments. The embodiments and descriptions in the specification are merely principles of the invention. Various changes and modifications can be made to the invention without departing from its spirit and scope, and all such changes and modifications fall within the scope of the claimed invention.

Claims

1. An offshore drilling platform, comprising a platform (1) and a cantilever beam base (2), characterized in that, The cantilever beam base (2) consists of a lower layer (201) of the cantilever beam base and a drilling platform (202). The drilling platform (202) is slidably connected to the top of the lower layer (201) of the cantilever beam base. The lower layer (201) of the cantilever beam base is slidably connected to the top of the platform (1). The top of the drilling platform (202) is fixedly equipped with a winch (3), a narrow derrick (4), an iron driller (10), a driller's cabin (13), and a crane (14).

2. The offshore drilling platform according to claim 1, characterized in that, The bottom layer (201) of the cantilever beam base is provided with a storage area (102) on top. A wellhead (101) is fixedly installed inside the storage area (102). The wellhead (101) is located on the side of the narrow derrick (4) away from the winch (3). A slide rail (401) is fixedly installed on the side of the narrow derrick (4) away from the winch (3).

3. The automated tubing handling system for an offshore drilling platform according to claim 2, characterized in that, The system includes a processing assembly comprising a lifting manipulator (8) fixedly mounted on the top of the lower layer (201) of the cantilever beam base, a pipe laying machine track (901), an upper clamping manipulator (12), and a cantilever crane (5) fixedly mounted on the top of the narrow derrick (4). The number of the pipe laying machine tracks (901) is set to two sets, and a horizontal pipe laying machine (9) is slidably connected to the top of each set of the pipe laying machine tracks (901).

4. The automated tubing handling system for an offshore drilling platform according to claim 3, characterized in that, The narrow derrick (4) has a traveling block (6) on one side, and a top drive (7) is fixedly connected to one end of the traveling block (6). The end of the traveling block (6) away from the top drive (7) is fixedly connected to the winch (3) after being limited and guided by the cantilever crane (5). The bottom of the top drive (7) is provided with a drill pipe (100).

5. An automated tubing handling system for an offshore drilling platform according to claim 4, characterized in that, A connecting rod (701) is fixedly installed on one side of the top drive (7). Two connecting rods (702) are hinged to the outer wall of the connecting rod (701). A sliding sleeve (703) is hinged to one end of the two connecting rods (702) away from the connecting rod (701). The sliding sleeve (703) is slidably connected to the outer wall of the slide rail (401).

6. An automated tubing handling system for an offshore drilling platform according to claim 5, characterized in that, The outer wall of the sliding sleeve (703) is hinged with a first electric push rod (704). The end of the first electric push rod (704) away from the sliding sleeve (703) is rotatably connected with a locking member (705). The locking member (705) is threadedly connected to the inside of the sliding sleeve (703) and abuts against the outer wall of the slide rail (401).

7. An automated tubing handling system for an offshore drilling platform according to claim 3, characterized in that, The narrow derrick (4) is equipped with a straightening manipulator (11). The straightening manipulator (11) includes a mounting base (1101) fixedly installed on the bottom crossbeam of the narrow derrick (4). The outer wall of the mounting base (1101) is hinged with a support arm (1102) and a second electric push rod (1103). The end of the second electric push rod (1103) away from the mounting base (1101) is hinged to the outer wall of the support arm (1102). The support arm (1102) is fixedly installed with a third electric push rod (1104). The support arm (1102) is slidably connected with a connector (1105). The third electric push rod (1104) is hinged inside the connector (1105).

8. An automated tubing handling system for an offshore drilling platform according to claim 7, characterized in that, The connector (1105) is fixedly connected to a connecting plate (1106) at one end away from the support arm (1102). A conical rotating sleeve (1107) is rotatably connected to the top of the connecting plate (1106). A fourth electric push rod (1108) is hinged to both sides of the connecting plate (1106). An arc-shaped hinge rod (1109) is hinged to one end of each of the two fourth electric push rods (1108) away from the connecting plate (1106). An arc-shaped rotating sleeve (1110) is rotatably connected to the top of each of the two arc-shaped hinge rods (1109). The two arc-shaped hinge rods (1109) are respectively hinged to the outer walls of both sides of the connecting plate (1106). The drill rod (100) is inserted between the conical rotating sleeve (1107) and the two arc-shaped rotating sleeves (1110).

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