Not Applicable
1. Field of the Invention
This invention relates to offshore platforms. More particularly, it relates to a method for assembling the tendons used to moor a tension leg platform.
2. Description of the Related Art including information disclosed under 37 CFR 1.97 and 1.98
A tension leg platform (TLP) is ideal for developing deepwater reserves. No other floating production facility design offers the optimal motion and stability characteristics of a tension leg platform. The TLP is vertically moored using tubular steel tendons and is supported by a buoyant hull. The tendon stiffness results in a system with virtually no heave, roll or pitch. This makes the TLP suitable for both dry tree and sub-sea completions.
A number of TLP solutions for deepwater field development have been designed, built and deployed around the world. The designs include both mono-column TLPs and mufti-column TLPs.
The key benefits of a TLP are:
All currently deployed TLPs have had their tendon systems installed by one of the following known methods:
Vertical Stalking.
Tendons are assembled offshore vertically at the surface by connecting joints of pipe vertically and lowering the assembly as additional joints are added to the string. The length of the joints is governed by the ability to handle and lift using a tall crane, and the availability of a tall assembly tower. Smaller facilities can be substituted when shorter joints are used, but assemblies of shorter joints require more time and more joints, and the cost of the couplings is increased.
One-Piece Wet Tow.
In this method, tendons are assembled by welding at a remote location (usually onshore) and subsequently towed in a horizontal orientation to the installation site. Tendons may be buoyant, neutrally buoyant or supported by floats to keep them at the surface. The top and bottom fittings are typically neither buoyant nor neutrally buoyant, and therefore require that floats be attached at each end of the tendon to provide support during the tow. Upon reaching the installation site, the tendon is upended by releasing selected floats while supporting the upper end from either the TLP or a support vessel.
Once the tendon is in the water and vertically oriented, the tendon can be either pre-installed by connecting its lower end to an existing anchor system and supporting its upper end with a temporary float, or co-installed by passing it over to the TLP to hang from the TLP vessel.
The present invention is a new method of assembling tendons offshore in a horizontal orientation using relatively low cost facilities.
A tendon is assembled at or near the installation site in a horizontal orientation using connectors or weld stations on a barge or other vessel. During assembly, the tendon is pulled away from the assembly vessel and tensioned by a tug or offshore work vessel. When fully assembled, the tendon is up-ended (in a manner similar to a wet-towed tendon) and then either preinstalled using floats or passed over to the TLP which is on-site and ready to receive the tendons.
The method of the invention can reduce both the fabrication and installation costs of TLP tendon system.
The costs of fabricating a tendon system and the installation of a tendon system are both related to the length of the individual pipe joints and the cost of the offshore support vessels needed to handle them.
The one piece we tow system requires a large on-shore facility to handle the long tendons as they are assembled, but requires a minimum offshore spread to up-end the tendons.
There are also the costs associated with the risk of a long tow (in both known examples of this type of installation, one or more tendons have been dropped during the tow). This configuration does not require any couplings, which can result in large cost savings.
Vertical stalking requires a vessel with the ability to handle joints of finished tendon pipe and a tower to hold the joint correctly aligned while the connection is made. For typical tendon joint lengths of 250 to 300 ft., a large offshore crane vessel is used which is a very expensive offshore spread.
Reducing the length of joints to 120 to 150 ft. allows a smaller crane and smaller tower to be used (lower day rate), but increases the assembly time and also increases the number of joints, thereby increasing cost in both of these areas.
The method of the present invention permits use a much lower cost barge (e.g., a pipe-lay barge) to assemble the tendon horizontally using long joints with either connectors or offshore welding. The offshore spread costs can be reduced from a large crane vessel, the assembly time is relatively short owing to the use of long joints, and the risks associated with a we tow are eliminated.
In the method of the present invention, a tendon is assembled at or near the installation site in a horizontal orientation using connectors or weld stations on a barge or other similar vessel. During assembly, the tendon is pulled away from the assembly vessel as its length progresses and tensioned by a tug or offshore work vessel. When fully assembled, the tendon may be up-ended in a manner similar to a wet-towed tendon, and then either preinstalled using floats or passed over to the TLP which is on-site and ready to receive the tendons.
Referring now to
Assembly vessel 10 may have one or more cranes 14 on deck 12 for lifting and transferring tendon segments 18 from supply vessel 16 (shown moored alongside vessel 10) to tendon supports 22 on deck 12. Tendon supports 22 are generally aligned with welding station 26, inspection station 28 and stinger 24. Stinger 24 may be supported by gantry 25 and may project from the aft end of vessel 10. Gantry 25 may be used to adjust the angle of stinger 24 relative to deck 12 (or the plane of supports 22). As will be appreciated by those skilled in the art, the horizontal plane of supports 22 is above the water line of vessel 10. Accordingly, that portion of tendon assembly 30 which is floating at or near the water surface will be at a different elevation than that portion which is supported on supports 22 on deck 12 of vessel 10. Stinger 24 may be used to minimize the bend radius of tendon 30 as it transitions from assembly vessel 10 into its horizontal floating position in the water.
Also shown in
As may best be seen in
Tendons may be assembled from tendon segments 18 by any suitable method. Most commonly, tendon segments 18 will be joined together by welding at station 26 and then pass to weld inspection station 28 for quality control purposes. Alternatively, tendon connectors may be installed at station 26 and clamped at station 28. In certain embodiments, floatation devices 32 may be installed at station 28 and/or 26.
Although the invention has been described in detail with reference to certain preferred embodiments, variations and modifications exist within the scope and spirit of the invention as described and defined in the following claims.
This application claims the benefit of U.S. Provisional Application No. 61/328,297, filed on Apr. 27, 2010.
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