APPARATUS FOR SUBSEA INTERVENTION

Abstract

A subsea intervention system is disclosed comprising a floating vessel and a source of coiled tubing at the floating vessel. The system includes a seabed installation including a wellhead and compliant guide having one end operatively connected to the floating vessel and the second end operatively connected to the seabed installation. The compliant guide provides a conduit between the floating vessel and the wellhead for the coiled tubing. At least one injector is present at the floating vessel for inserting the coiled tubing into the compliant guide, and a carousel is proximate the wellhead which comprises a plurality of chambers with intervention tools in at least two of those chambers. The system may also include a plurality of sensing units that are disposed at spaced intervals along the compliant guide to monitor various aspects of the compliant guide and to transmit that information to a repositioning system. A riser may be used instead of the compliant guide.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in-part of a co-pending U.S. patent application Ser. No. 11/566,258, filed on Dec. 4, 2006, which is a continuation-in-part of U.S. patent application Ser. No. 10/709,322, filed Apr. 28, 2004, now U.S. Pat. No. 7,264,057, which is a continuation of U.S. patent application Ser. No. 09/920,896, filed Aug. 2, 2001, now U.S. Pat. No. 6,763,889, which claims the benefit under 35 U.S.C. §119(e) of U.S. Provisional Application Ser. Nos. 60/225,230, filed Aug. 14, 2000; 60/225,440, filed Aug. 14, 2000; and 60/225,439, filed Aug. 14, 2000. U.S. patent application Ser. No. 11/566,258 also claims the benefit under 35 U.S.C. §119(e) of U.S. Provisional Application Ser. No. 60/745,364, filed Apr. 21, 2006. Each of the above applications are incorporated herein by reference in their entirety.

TECHNICAL FIELD

The present invention relates to apparatus for making subsea interventions and more particularly for making such interventions using a compliant guide, e.g., a spoolable compliant guide.

BACKGROUND

An operator may perform a subsea well intervention for various reasons including, for example, in response to a drop in production or some other problem in the subsea well. Such an intervention operation may involve running a monitoring tool into the subsea well to identify the problem, and depending on the type of problem encountered, the intervention may further include such steps as shutting in one or more zones, pumping a well treatment into a well, or lowering tools to actuate downhole devices (e.g., valves).

The performance of a conventional subsea intervention requires the operator to deploy a rig (such as a semi-submersible rig) or a vessel, as well as a marine riser, which is a large diameter tubing that extends from the rig or vessel to the subsea wellhead equipment. Performing intervention operations with large vessels and heavy equipment such as marine riser equipment is typically time consuming, labor intensive, and expensive. Accordingly, such conventional intervention is only performed when economics and risks are favorable. In other cases, the well performance is simply accepted without intervention. As a result, subsea wells typically produce less and for a shorter duration than platform wells.

Many subsea well operators attempt to predict future needs of the subsea wells by installing expensive completion equipment that would enable the subsea wells to fulfill these future needs without the necessity of performing a well intervention operation. Installation of such equipment substantially increases the cost to complete the subsea well. However, since the reservoir description and its dynamic behavior are usually better deciphered and understood over time, it is likely that some anticipated future needs might not materialize and some unexpected ones might appear. In other words, some of the costly completion equipment may never be utilized and equipment which turns out to be needed may not be present at the subsea wells. Nonetheless, many subsea well operators install this expensive completion equipment and accept the consequences, whatever way they may turn out, instead of performing an intervention.

A spoolable compliant guide (“SCG”) has been proposed for use in a subsea intervention operation. An SCG is constructed as a hollow tube which may be continuous or jointed, and has a first end for engagement with a floating vessel and a second end engaging a subsea wellhead. The SCG acts as a conduit between the floating vessel and the subsea wellhead for coiled tubing. Such an SCG is described in U.S. Pat. No. 6,386,290 to Headworth, which is owned by the Assignee of the present application and which is incorporated herein by reference.

DISCLOSURE OF THE INVENTION

In accordance with the present invention, a subsea intervention system is provided which comprises a floating vessel with a source of coiled tubing at the floating vessel. The system further includes a seabed installation which includes a wellhead, and a compliant guide having first and second ends. The compliant guide may be a spoolable compliant guide (SCG). Hence, any discussion of compliant guide is also applicable to SCG. The first end of the compliant guide is operatively connected to the floating vessel and the second end of the compliant guide is operatively connected to the seabed installation. This compliant guide provides a conduit between the floating vessel and the wellhead for the coiled tubing. A system in accordance with the present invention also includes at least one injector at the floating vessel for inserting the coiled tubing into the compliant guide.

A subsea carousel is provided proximate the wellhead which comprises a plurality of chambers with intervention tools in at least two of said chambers. The coiled tubing utilizes the tools in the carousel during intervention procedures. The intervention tools that are present in the chambers of the carousel may, for example, be bottom hole assemblies, crown plugs and intervention work tools.

In one embodiment of the system of the present invention, the carousel is operatively connected to the second end of the compliant guide as the compliant guide is lowered to the seabed installation. In yet another embodiment of the present invention, the carousel is operatively connected to and is part of the seabed installation.

A system according to the present invention may further comprise a plurality of sensing units which are disposed at spaced intervals along the compliant guide. The sensing units function to measure the magnitude and direction of forces acting on the compliant guide and to transmit that information to vessel repositioning apparatus located proximate the floating vessel. The vessel repositioning apparatus utilizes the information from the sensors to reposition the floating vessel as required. The various sensors that are disposed on the compliant guide may also be used to monitor a variety of aspects of the compliant guide, including its radius, pressure, ovality, wall thickness and movements in three-dimensional space.

In an alternative aspect, the intervention system, comprises a floating vessel, a source of coiled tubing at the floating vessel and a seabed installation which has a wellhead. A compliant guide is also included, which has first and second ends, the first end being operatively connected to the floating vessel and the second end operatively connected to the seabed installation. The compliant guide provides a conduit between the floating vessel and the wellhead for the coiled tubing. At least one injector at the floating vessel is provided for pushing the coiled tubing into the compliant guide. A carousel proximate the wellhead is also included. The carousel comprises a plurality of chambers with intervention tools in at least two of such chambers. This system further includes a plurality of sensing units present at spaced intervals along the compliant guide and a filter mechanism disposed between the wellhead and a flow line for filtering undesirable solids from the wellhead. The sensing units monitor the radius, pressure, ovality, wall thickness and movements in three-dimensional space of the compliant guide. The compliant guide also includes a rudder assembly for controlling movement of the compliant guide.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

Implementations of the invention may be better understood when consideration is given to the following detailed description thereof. Such description makes reference to the annexed pictorial illustrations, schematics, graphs, drawings, and appendices. In the drawings:

FIG. 1 is an elevation view which illustrates an SCG being lowered to a subsea assembly.

FIG. 2 is an elevation view which illustrates the SCG of FIG. 1 as it assumes a desired compliant shape.

FIG. 3 is a schematic diagram which illustrates a filter mechanism disposed between a wellhead and a flowline.

FIG. 4 is a top view of one embodiment of a filter mechanism as illustrated in FIG. 3.

FIG. 5 is a perspective view of the carousel 210 which is illustrated in FIGS. 1 and 2.

FIG. 6 is a top view of a rudder assembly which may be utilized in the system of the present invention.

FIG. 7 is a schematic diagram in block diagram form of the control system 626 illustrated in FIG. 6.

FIG. 8 is a view of a riser, in partial cross-section, which may be used in alternative embodiments of the invention.

FIG. 9 is an elevation view which illustrates a riser being lowered to a subsea assembly.

FIG. 10 is an elevation view which illustrates the riser of FIG. 9 as it assumes a desired compliant shape.

FIG. 11 is a schematic diagram which illustrates a filter mechanism disposed between a wellhead and a flowline in the embodiment of FIGS. 9 and 10.

FIG. 12 is a top view of one embodiment of a filter mechanism as illustrated in FIG. 11.

FIG. 13 is a perspective view of the carousel 910 which is illustrated in FIGS. 9 and 10.

FIG. 14 is a top view of a rudder assembly which may be utilized in the system of the FIGS. 9-13 of the invention.

FIG. 15 is a schematic diagram in block diagram form of the control system 926 illustrated in FIG. 14.

DETAILED DESCRIPTION

It will be appreciated that the present invention may take many forms and embodiments. In the following description, some embodiments of the invention are described and numerous details are set forth to provide an understanding of the present invention. Those skilled in the art will appreciate, however, that the present invention may be practiced without those details and that numerous variations from and modifications of the described embodiments may be possible. The following description is thus intended to illustrate and not limit the present invention.

Various embodiments and aspects of the invention will now be described in detail with reference to the accompanying figures. Furthermore, the terminology and phraseology used herein is solely used for descriptive purposes and should not be construed as limiting in scope. Language such as “including,” “comprising,” “having,” “containing,” or “involving,” and variations thereof, is intended to be broad and encompass the subject matter listed thereafter, equivalents, and additional subject matter not recited. Further, whenever a composition, a group of elements or any other expression is preceded by the transitional phrase “comprising”, “including” or “containing”, it is understood that we also contemplate the same composition, the group of elements or any other expression with transitional phrases “consisting essentially of”, “consisting”, or “selected from the group of consisting of”, preceding the recitation of the composition, the group of elements or any other expression.

The term “system” may also be referred to herein as “apparatus”.

Referring now to FIGS. 1 and 2, an SCG 30 is illustrated being lowered to the subsea lubricator 40 by two injectors 22, 23 in series. Injectors 22 and 23 are utilized to lower SCG 30, and to push coiled tubing 21 from coiled tubing assembly 20 into SCG 30. A remote operated vehicle 60 guides the tool string 24 into the subsea lubricator 40, which has a larger inside diameter than the outside diameter of the tool string 24. The SCG 30 and coiled tubing assembly 20 may be lowered until the coiled tubing tool string 24 is fully inserted into, and the latching apparatus 36 mates with, the subsea lubricator 40. The SCG 30 continues to be unspooled until it assumes a desired compliant shape as illustrated in FIG. 2 and until it is clear of the injectors 22, 23. In FIGS. 1 and 2, 31 depicts a hang-off flange, 32 depicts the SCG main body, 43 depicts a bottom stack assembly (or intervention package), 50 depicts a wellhead, 41 depicts a control umbilical connection and 111 indicates the surface of water.

The SCG 30 is of sufficient length to reach between the floating vessel 10 and the subsea lubricator 40 and assumes a compliant shape, while the coiled tubing 21 is of sufficient length to penetrate to the depths of the well 51 and is generally much longer than the SCG 30.

The compliant quality of the SCG 30 as it extends from the subsea lubricator 40 to the floating vessel 10 enables dynamic bending and thus provides a means of compensation for the heave motions of the floating vessel 10 and thereby avoids the need for special heave compensation devices for both the SCG 30 and the injectors 22 and 23.

The SCG 30 may also include secondary force sensing units 105 located at a plurality of positions along the length of the SCG 30, as shown in FIG. 3. These units 105 contain sensors, associated electronics to determine the magnitude and direction of forces acting on the SCG 30 at positions 106a-c as well as communication hardware and software (not shown) for transmitting the information to a vessel response unit 107 which includes communication electronics, communication hardware and software (not shown) and a vessel repositioning apparatus 108 such as a propeller.

Apparatus according to the present invention has the following features, namely: (a) stress/strain analysis modeling of the SCG; (b) a subsea handling system; (c) a subsea carousel for storing intervention tools; and (d) a solids filtering mechanism. Each of these features is discussed below.

Stress/Strain Analysis Modeling of the SCG

In accordance with the present invention, the fatigue and life of SCG 30 may be modeled in real time as the SCG 30 moves and bends under the sea. Various techniques may be directed to monitoring the stress and movement of the SCG 30, analyzing the data and determining the remaining life of SCG 30. Various parameters that may be monitored include radius, pressure, ovality of the tubing, wall thickness, x, y and z movements, and the like. These parameters may be measured using various sensors and the fiber optic disposed along the SCG 30. Examples of those sensors may include the sensor units 105 shown in FIG. 2. In one implementation, a GPS may be used in monitoring those parameters. The life value of the SCG 30 may then be used to replace or adjust the SCG 30 prior to it reaching a failure stress point. Various methods for modeling stress/strain on a wireline coiled tubing system may be described in commonly assigned U.S. Pat. No. 5,826,654 entitled MEASURING RECORDING AND RETRIEVING DATA ON COILED TUBING SYSTEM and U.S. Pat. No. 7,357,179, entitled METHODS OF USING COILED TUBING INSPECTION DATA, which are incorporated herein by reference.

In this manner, various stress/strain parameters of the SCG 30 may be monitored and analyzed. The life remaining in the SCG 30 may then be calculated based on the stress/strain parameters.

Subsea Handling System

Various technologies may also be directed to a subsea handling system, which may be defined as equipment for deploying the SCG 30 into the sea. In one implementation, the subsea handling system may include a cantilever, which may be disposed at the back or the side of a vessel. In another implementation, the subsea handling system may include a heave compensation mechanism. The subsea handling system may enable any common vessel having a large deck space to be used for deploying the SCG 30, thereby eliminating the necessity of using only vessels having a moon pool. However, the subsea handling system may also be used with a vessel having a moon pool.

The primary purpose of the subsea handling system is to manage the safe handling of a subsea well control system from the back of a supply class or anchor handling vessel. In one implementation, the subsea handling system may be a stand alone equipment with respect to the vessel's structure, thereby forming an integral part of the well intervention spread.

The subsea handling system may utilize a number of deployment means, such as a high tensile cable, a plasma style rope, or coiled tubing.

In one implementation, the subsea handling system may include a deck skidding system, an a-frame (or similar) style heavy lift crane, a cursor launching/receiving system (to all safe passage of the lifted package through the splash zone).

The subsea handling system may be configured to manage the handling of the package across its entire axis of freedom, limiting any movement while deploying or retrieving the hardware to/from the seabed.

The deployment/retrieval system may use a series of hydraulically operated arms to alter the hardware from the horizontal to the vertical planes (or vice versa). This system may also include a platform where the complete well control and lubricator section of the subsea hardware is supported and maneuvered from horizontal to vertical, with the vertical position being located directly above the cursor launching system either at the rear or on the side of vessel.

In one implementation, the subsea handling system may include an integral active heave compensation system.

In another implementation, the subsea handling system may use “anchor handling vessel anchor forks” as a method of support the lift load or cantilever loads.

In yet another implementation, the lifting/landing system may include a plasma rope system for use in making up the well control package to the subsea Christmas tree. This system may include either surface or subsea winches for final stages of make-up.

Solids Filtering Mechanism

Subsea wellheads are typically connected to each other using flow lines, which may then be connected to a production tubing to the surface. In addition to fluids, the well may produce unwanted solids. Accordingly, various technologies may be directed to a filter mechanism 301 disposed between a wellhead 302 and a flow line for filtering unwanted solids from the wellhead, as schematically shown on FIG. 3. An ROV may be used to position such filter mechanisms. In one implementation, the filter mechanism 301 may include a cylindrical body 301a having a number of slots 301b contained therein, as illustrated in FIG. 4. A filter cartridge (not shown) may be disposed in each slot 301b. Such a filter mechanism 301 may be configured to be used with a number of wellheads on the sea floor. By using the filter mechanism 301, fluids from the wellhead may be produced to the surface with minimal unwanted solids.

Subsea Carousel/Revolver for Storing Intervention Tools

The time it would take the SCG 30 to reach down to the sea floor and secure it to the wellhead may be hours, even days. Accordingly, it would be desirable to minimize the number of times the SCG 30 is brought up to the surface. Various intervention work tools, bottom hole assemblies (BHA's), crown plugs and the like may be used as part of a subsea intervention on a wellhead.

Implementations of various technologies described herein may be directed to a revolver/carousel type storage unit having slots or launch tubes disposed therein. Each slot may be configured to store an intervention work tool, a BHA, a crown plug and the like during a subsea intervention. The storage unit may be configured to rotate to facilitate access to various tools and crown plugs stored in the slots.

FIG. 5 illustrates a carousel storage unit 210 that may be used in accordance with the present invention. The carousel storage unit 210 may be used to enable easy exchange of intervention tools attached to the SCG 30 without retrieving the SCG 30 all the way back to the sea vessel. As further shown in FIG. 5, the carousel storage unit 210 may have a rotatable structure 214 with a plurality of chambers 212, with each chamber containing a respective intervention tool. The rotatable structure 214 may be rotatable about an axis 216. In one implementation, depending on the desired type of intervention tool, the rotatable structure 214 is rotated so that the appropriate chamber 212 may be aligned with the wellhead. The coiled tubing may be lowered into the chamber 212 for engagement with the tool in the chamber 212. Further downward movement of the coiled tubing may cause the tool to be run into the wellbore.

After the first intervention operation has been completed, the coiled tubing may be raised. The intervention tool connected at the end of the coiled tubing may be raised into the corresponding chamber 212, where the intervention tool is unlatched from the coiled tubing. The coiled tubing may be raised out of the storage unit 210. Subsequently, the storage unit 210 may be actuated and the rotatable structure 214 may be rotated so that another chamber 212 containing another type of intervention tool is aligned with the wellhead. The coiled tubing may again be lowered into chamber 212, where it engages the next intervention tool. Another intervention operation may then be performed. This process may be repeated until all desired intervention operations possible with tools contained in the storage unit 210 have been performed.

In one embodiment, carousel 210 is operatively connected to SCG30 as SCG30 is lowered. In another embodiment, carousel 210 is operatively connected to and is part of the wellhead.

As indicated above, the slots or launch tubes may be accessible to the wellbore by either a carousel design method, independent tubes activated to centerline of bore by hydraulic means, by way of a linear sliding cassette, or by an automated tool changer (similar to a machine tool—tool handler/changer). The number of launch tubes may depend on the desired campaign. It is envisioned that the storage unit may include as many as 12 launch tubes or more.

The launch tubes may contain hydraulic rams, which may be used in the removal and replacement of Christmas tree plugs. The storage unit may allow a single ram to be located over the wellbore centerline and through hydraulic extension of the ram, lock onto the top of the HXT (horizontal Christmas tree) plug and retrieve the plug. The end assembly of the ram may have a device that may allow accelerated forces onto the plug locking device to encourage movement.

The upper end of the launch tubes may have a remotely latchable interface to allow an internal coiled tubing workstring (deployed from surface) to latch onto the tool located within the tube. The same device may have an automated capability that, once workstring has completed its in-well activity and returned the tool back into the tube, it can be disconnected from the tool, allowing the coiled tubing to return to surface leaving tool subsea.

The internals of the launching system may either be exposed to hydrocarbons at all times, or have the ability to be purged and operate in a manner similar to an airlock.

In one implementation, the storage unit may be attached to the wellhead, perhaps below the stripper. In another implementation, the storage unit may be mounted either above or below the subsea well control package.

The storage unit may be controlled remotely from the surface using a control line. In one implementation, the storage unit may be remotely controlled from the surface by direct or multiplexed control methods. The control of the storage unit may have an interlock with the well control settings of the subsea package.

The storage unit may be used in connection with a compliant guide using coiled tubing where the i.d. of the compliant guide is smaller, that is where the tool/device required to enter the well is larger than the i.d. of the compliant guide. As such, the storage unit may be used to store the tools/devices used for entering the well.

The storage unit may contain internal cameras for monitoring the activity within the launch tubes or the latching of the plugs.

The storage unit may have an inlet and outlet to allow the flushing of any hydrocarbons from within. The returns may either be transferred back into the subsea well or returned to surface for handling.

Rudders for Controlling Movements of SCG

If the SCG 30 is exposed to strong currents, such as those in Gulf of Mexico, the SCG 30 may have several locked up points due to forces caused by opposing currents. Accordingly, various technologies may be directed to attaching a plurality of rudders along the SCG 30 for controlling the movements of the SCG 30. The rudders may be horizontal rudders or vertical rudders. Various parameters, e.g., the pitch, angle and the like, of the rudders, may be controlled by the various sensors and the fiber optic line disposed along the SCG 30. In this manner, the rudders may be used to control the geometry of the SCG 30. In one implementation, the rudders may be used to move the SCG 30 from one wellhead to another wellhead. In another implementation, the rudders may be used in combination with the buoyancy/air bags. In yet another implementation, the rudders may be used in lieu of the buoyancy mechanisms/air bags.

FIG. 6 schematically illustrates a rudder assembly 610 in accordance with implementations of various technologies described herein. The rudder assembly 610 is provided with two opposed control surfaces, or wings, 624, which may be molded from a fiber-reinforced plastics material, which project horizontally outwardly from the body 612 and which may be independently rotatable about a common axis extending substantially perpendicularly through the longitudinal axis of the body. Rotation of the wings 624 may be controlled by a control system 626 sealingly housed within the body 612. To facilitate the rapid removal and reattachment, the wings 624 may be secured to body 612 by a quick-release attachment 630.

FIG. 7 illustrates the control system 626 of FIG. 6 in more detail. In particular, the control system 626 may include a microprocessor-based control circuit 734 having respective inputs 735 to 739 to receive control signals representative of desired depth 735, actual depth 736, desired lateral position 737, actual lateral position 738 and roll angle 739 of the rudder 610. The desired depth signal can be either a fixed signal corresponding to the aforementioned 10 meters, or an adjustable signal, while the actual depth signal is typically produced by a depth sensor 740 mounted in or on the rudder 610. The roll angle signal 739 may be produced by an inclinometer 742 mounted within the rudder 610. In an alternative embodiment, the intervention system, comprises a floating vessel, a source of coiled tubing at the floating vessel and a seabed installation which has a wellhead. A compliant guide is also included, which has first and second ends, the first end being operatively connected to the floating vessel and the second end is operatively connected to the seabed installation. The compliant guide provides a conduit between the floating vessel and the wellhead for the coiled tubing. At least one injector at the floating vessel is provides for pushing the coiled tubing into the compliant guide. A carousel proximate the wellhead is also a part of this embodiment. The carousel comprises a plurality of chambers with intervention tools in at least two of such chambers. This system further includes a plurality of sensing units present at spaced intervals along the compliant guide and a filter mechanism disposed between the wellhead and a flow line for filtering undesirable solids from the wellhead. The sensing units monitor the radius, pressure, ovality, wall thickness and movements in three-dimensional space of the compliant guide. The compliant guide also includes a rudder assembly for controlling movement of the compliant guide.

Alternative Embodiments

In alternative embodiments, a riser may be used instead of the compliant guide or spoolable compliant guide in the intervention system of this invention, to make subsea interventions, as described herein. The riser may be made of a flexible pipe, such as is frequently used in subsea oilfield applications. The riser is used in substantially the same manner as the compliant guide or spoolable compliant guide to perform all the functions of the system of this invention. These embodiments are described below.

Risers made from a flexible pipe are known in the art. FIG. 8 illustrates a typical construction of a flexible pipe 500, which can form a riser used in this invention. The layers and their respective functions and characteristics are described below:

• • Layer 502—Interlocked steel carcass—resistant to hydrostatic pressure, to radial compression during installation and supportive of the inner thermoplastic sheath. It is generally manufactured from stainless steel.
  • Layer 504—Inner thermoplastic sheath—promotes sealing, and prevents internal fluids (oil, gas or water) from permeating through the external layers. It is manufactured from nylon or a similar material.
  • Layer 506—Interlocked steel pressure layer—resistant to internal pressure and hydrostatic pressure and to radial compression. It is usually manufactured from carbon steel, and covered with a layer of anti-wear tape.
  • Layers 508a and 508b—double-cross wound tensile armor layers—resistant to axial forces, to internal pressure and to torsion. The two (or more) tensile armor layers are separated by an anti-wear tape (not shown).
  • Layer 510—external thermoplastic sheath—protects the internal layers against external agents, like corrosion and abrasion, and maintains the double-cross wound tensile armors in a tied state and assures the sealing of the pipe. It is usually manufactured from a polymer, e.g., nylon.

In this embodiment utilizing a riser, a subsea intervention system is provided which comprises a floating vessel with a source of coiled tubing at the floating vessel. The system includes a seabed installation which includes a wellhead, and a riser having first and second ends. The first end of the riser is operatively connected to the floating vessel and the second end of the riser is operatively connected to the seabed installation. The riser provides a conduit between the floating vessel and the wellhead for the coiled tubing. A system in accordance with this embodiment of the invention also includes at least one injector and usually at least two injectors, at the floating vessel for inserting the coiled tubing into the riser.

A subsea carousel is provided proximate the wellhead which comprises a plurality of chambers with intervention tools in at least two of the chambers. The coiled tubing utilizes tools in the carousel during intervention procedures. The intervention tools that are present in the chambers of the carousel may, for example, be bottom hole assemblies, crown plugs and intervention work tools.

In one aspect of this embodiment of the system of the invention, the carousel is operatively connected to the second end of the riser as the riser is lowered to the seabed installation. In yet another embodiment, the carousel is operatively connected to and is part of the seabed installation.

A system according to this embodiment of the invention may further include a plurality of sensing units which are disposed at spaced intervals along the riser. The sensing units function to measure the magnitude and direction of forces acting on the riser and to transmit that information to a vessel repositioning apparatus located proximate the floating vessel. The vessel repositioning apparatus utilizes the information from the sensors to reposition the floating vessel as required. The various sensors that are disposed on the riser may also be used to monitor a variety of aspects of the riser, including its radius, pressure, ovality, wall thickness and movements in three-dimensional space.

In another aspect of these alternative embodiments, the intervention system comprises a floating vessel, a source of coiled tubing at the floating vessel and a seabed installation which has a wellhead. A riser is also included, which has first and second ends, the first end being operatively connected to the floating vessel and the second end operatively connected to the seabed installation. The riser provides a conduit between the floating vessel and the wellhead for the coiled tubing. At least one injector at the floating vessel provides for pushing the coiled tubing into the riser. A carousel proximate the wellhead is also a part of this aspect. The carousel comprises a plurality of chambers with intervention tools in at least two of such chambers. This system further includes a plurality of sensing units present at spaced intervals along the riser and a filter mechanism disposed between the wellhead and a flow line for filtering undesirable solids from the wellhead. The sensing units monitor the radius, pressure, ovality, wall thickness and movements in three-dimensional space of the riser. The riser also includes a rudder assembly for controlling movement of the compliant guide.

Description of Specific Alternative Embodiments

As discussed above, the riser may be made from a flexible pipe, and thus is able to assume a compliant shape as it is lowered undersea towards the seabed installation. Such a riser made from a flexible pipe is used in the embodiments described below.

Referring now to FIGS. 9 and 10, a riser 730 made of a flexible pipe is illustrated being lowered to the subsea lubricator 740 by two injectors 722, 723 in series. Injectors 722 and 723 are utilized to lower the riser 730, and to push coiled tubing 721 from coiled tubing assembly 720 into the riser 730. Alternatively, the riser 730 may be lowered to the seabed installation in any conventional manner. A remotely operated vehicle 760 guides the tool string 724 into the subsea lubricator 740, which has a larger inside diameter than the outside diameter of the tool string 724. The riser 730 and coiled tubing assembly 721 may be lowered until the coiled tubing tool string 724 is fully inserted into, and the latching apparatus 736 mates with, the subsea lubricator 740. The riser 730 continues to be lowered until it assumes a desired compliant shape as illustrated in FIG. 10 and until it is clear of the injectors 722, 723. In FIGS. 9 and 10, 731 depicts a hang-off flange, 732 depicts the SCG main body, 743 depicts a bottom-stack assembly (or intervention package), 750 a wellhead, 741 depicts a control umbilical connection and 811 indicates the surface of water.

The riser 730 is of sufficient length to reach between the floating vessel 710 and the subsea lubricator 740 and assumes a compliant shape, while the coiled tubing 721 is of sufficient length to penetrate to the depths of the well 751 and is generally much longer than the riser 730.

The compliant quality of the riser 730 as it extends from the subsea lubricator 740 to the floating vessel 710 enables dynamic bending and thus provides a means of compensation for the heave motions of the floating vessel 710 and avoids the need for special heave compensation devices for both the riser 730 and the injectors 722 and 723.

The riser 730 may also include secondary force sensing units 805 located at a plurality of positions along the length of the riser 730, as shown in FIG. 10. These units 805 contain sensors, and associated electronics to determine the magnitude and direction of forces acting on the riser 730 at positions 806a-c as well as communication hardware and software (not shown) for transmitting the information to a vessel response unit 807, which includes communication electronics, communication hardware and software (not shown) and a vessel repositioning apparatus 808 such as a propeller.

Apparatus of this embodiment of the invention includes the following features: (a) stress/strain analysis modeling of the riser; (b) a subsea handling system; (c) a subsea carousel for storing intervention tools; and (d) a solids filtering mechanism. Each of these features is discussed below.

Stress/Strain Analysis Modeling of the Riser

In the embodiments of the present invention, the fatigue and life of the riser 730 may be modeled in real time as the riser moves and bends under the sea. Various techniques may be directed to monitoring the stress and movement of the riser 730, analyzing the data and determining the remaining life of riser 730. Various parameters that may be monitored include radius, pressure, ovality of the tubing, wall thickness, x, y and z movements, and similar parameters. These parameters may be measured using various sensors and the fiber optic disposed along the riser 730. Examples of those sensors may include the sensor units 805 shown in FIG. 10. In one aspect, a GPS may be used in monitoring those parameters. The life value of the riser 730 may then be used to replace or adjust the riser 730 prior to it reaching a failure stress point. Various methods for modeling stress/strain on a wireline coiled tubing system may be described in commonly assigned U.S. Pat. No. 5,826,654 entitled MEASURING RECORDING AND RETRIEVING DATA ON COILED TUBING SYSTEM and U.S. Pat. No. 7,357,179, entitled METHODS OF USING COILED TUBING INSPECTION DATA, which are incorporated herein by reference.

In this manner, various stress/strain parameters of the riser 730 may be monitored and analyzed. The life remaining in the riser 730 may then be calculated based on the stress/strain parameters.

Subsea Handling System

Various technologies may also be directed to a subsea handling system, which may be defined as equipment for deploying the riser 730 into the sea. In one aspect of the invention, the subsea handling system may include a cantilever, which may be disposed at the back or the side of a vessel. In another aspect, the subsea handling system may include a heave compensation mechanism. The subsea handling system may enable any common vessel having a large deck space to be used for deploying the riser 730, thereby eliminating the necessity of using only vessels having a moon pool. However, the subsea handling system may also be used with a vessel having a moon pool.

The primary purpose of the subsea handling system is to manage the safe handling of a subsea well control system from the back of a supply class or anchor handling vessel. In one aspect, the subsea handling system may be a stand alone equipment with respect to the vessel's structure, thereby forming an integral part of the well intervention spread itself.

The subsea handling system may utilize a number of deployment means, such as a high tensile cable, a plasma style rope, or coiled tubing.

In one implementation, the subsea handling system may include a deck skidding system, an a-frame (or similar) style heavy lift crane, a cursor launching/receiving system (to all safe passage of the lifted package through the splash zone).

The subsea handling system may be configured to manage the handling of the package across its entire axis of freedom, limiting any movement while deploying or retrieving the hardware to/from the seabed.

The deployment/retrieval system may use a series of hydraulically operated arms to alter the hardware from the horizontal to the vertical planes (or vice versa). This system may also include a platform where the complete well control and lubricator section of the subsea hardware is supported and maneuvered from horizontal to vertical, with the vertical position being located directly above the cursor launching system either at the rear or on the side of vessel.

In one aspect of the invention, the subsea handling system may include an integral active heave compensation system.

In another aspect, the subsea handling system may use an “anchor handling vessels anchor forks” as a method of support the lift load or cantilever loads.

In yet another implementation, the lifting/landing system may include a plasma rope system for use in making up the well control package to the subsea Christmas tree. This system may include either surface or subsea winches for final stages of make-up.

Solids Filtering Mechanism

Subsea wellheads are typically connected to each other using flow lines, which may then be connected to a production tubing to the surface. In addition to fluids, the well may produce unwanted solids. Accordingly, various technologies may be directed to a filter mechanism 901 disposed between a wellhead 902 and a flow line for filtering unwanted solids from the wellhead, as schematically shown in FIG. 11. An ROV may be used to position such filter mechanisms. In one implementation, the filter mechanism 901 may include a cylindrical body 901a having a number of slots 901b contained therein, as illustrated in FIG. 12. A filter cartridge (not shown) may be disposed in each slot 901b. Such a filter mechanism 901 may be configured to be used with a number of wellheads on the sea floor. By using the filter mechanism 901, fluids from the wellhead may be produced to the surface with minimal unwanted solids.

Subsea Carousel/Revolver for Storing Intervention Tools

The time it would take the riser 730 to reach down to the sea floor and secure it to the wellhead may be hours, or even days. Accordingly, it would be desirable to minimize the number of times the riser 730 is brought up to the surface. Various intervention work tools, bottom hole assemblies (BHA's), crown plugs and similar tools may be used as part of a subsea intervention on a wellhead.

Implementations of various technologies described herein may be made with a revolver/carousel type storage unit having slots or launch tubes disposed therein. Each slot may be configured to store an intervention work tool, a BHA, a crown plug and similar tools during a subsea intervention. The storage unit may be configured to rotate to facilitate access to various tools and crown plugs stored in the slots.

FIG. 13 illustrates a carousel storage unit 910 that may be used in the invention. The carousel storage unit 910 may be used to enable easy exchange of intervention tools attached to the riser 730 without retrieving the riser 730 all the way back to the sea vessel. As further shown in FIG. 13, the carousel storage unit 910 may have a rotatable structure 914 with a plurality of chambers 912, with each chamber containing a respective intervention tool. The rotatable structure 914 may be rotatable about an axis 916. In one implementation, depending on the desired type of intervention tool, the rotatable structure 914 is rotated so that the appropriate chamber 912 may be aligned with the wellhead. The coiled tubing may be lowered into the chamber 912 for engagement with the tool in the chamber 912. Further downward movement of the coiled tubing may cause the tool to be run into the wellbore.

After the first intervention operation has been completed, the coiled tubing may be raised. The intervention tool connected at the end of the coiled tubing may be placed into the corresponding chamber 912, where the intervention tool is unlatched from the coiled tubing. The coiled tubing may be raised out of the storage unit 910. Subsequently, the storage unit 910 may be actuated and the rotatable structure 914 may be rotated so that another chamber 912 containing another type of intervention tool is aligned with the wellhead. The coiled tubing may again be lowered into chamber 912, where it engages the next intervention tool. Another intervention operation may then be performed. This process may be repeated until all desired intervention operations possible with tools contained in the storage unit 910 have been performed.

In one embodiment, carousel 910 is operatively connected to riser 730 as the riser is lowered. In another embodiment, carousel 910 is operatively connected to and is part of the wellhead.

As indicated above, the slots or launch tubes may be accessible to the wellbore by either a carousel design method, independent tubes activated to centerline of bore by hydraulic means, by way of a linear sliding cassette, or by an automated tool changer (similar to a machine tool—tool handler/changer). The number of launch tubes may depend on the desired campaign. It is envisioned that the storage unit may include as many as 12 launch tubes or more.

The launch tubes may contain hydraulic rams, which may be used in the removal and replacement of Christmas tree plugs. The storage unit may allow a single ram to be located over the wellbore centerline and through hydraulic extension of the ram, lock onto the top of the HXT (horizontal Christmas tree) plug and retrieve the plug. The end assembly of the ram may have a device that may allow accelerated forces onto the plug locking device to encourage movement.

The upper end of the launch tubes may have a remotely latchable interface to allow an internal coiled tubing workstring (deployed from surface) to latch onto the tool located within the tube. The same device may have an automated capability that, once the workstring has completed its in-well activity and returned the tool back into the tube, it can be disconnected from the tool, allowing the coiled tubing to return to surface leaving tool subsea.

The internals of the launching system may either be exposed to hydrocarbons at all times, or have the ability to be purged and operate in a manner similar to an airlock.

In one implementation, the storage unit may be attached to the wellhead, perhaps below the stripper. In another implementation, the storage unit may be mounted either above or below the subsea well control package.

The storage unit may be controlled remotely from the surface using a control line. In one implementation, the storage unit may be remotely controlled from the surface by direct or multiplexed control methods. The control of the storage unit may have an interlock with the well control settings of the subsea package.

The storage unit may be used in connection with a riser where the i.d. of the riser is smaller than the required tool/device entering the well.

The storage unit may contain internal cameras for monitoring the activity within the launch tubes or the latching of the plugs.

The storage unit may have an inlet and outlet to allow the flushing of any hydrocarbons from within. The returns may either be transferred back into the subsea well or returned to surface for handling.

Rudders for Controlling Movements of SCG

If the riser 730 is exposed to strong currents, such as those in Gulf of Mexico, the riser 730 may have several locked up points due to forces caused by opposing currents. Accordingly, various technologies may be directed to attaching a plurality of rudders along the riser 730 for controlling the movements of the riser 730. The rudders may be horizontal rudders or vertical rudders. Various parameters, e.g., the pitch, angle and similar parameters of the rudders, may be controlled by the various sensors and the fiber optic line disposed along the riser 730. In this manner, the rudders may be used to control the geometry of the riser 730. In one implementation, the rudders may be used to move the riser 730 from one wellhead to another wellhead. In another implementation, the rudders may be used in combination with the buoyancy/air bags. In yet another implementation, the rudders may be used in lieu of the buoyancy mechanisms/air bags.

FIG. 14 schematically illustrates a rudder assembly 910 in accordance with implementations of various technologies described herein. The rudder assembly 910 is provided with two opposed control surfaces, or wings, 924, which may be molded from a fiber-reinforced plastics material, which project horizontally outwardly from the body 912 and which may be independently rotatable about a common axis extending substantially perpendicularly through the longitudinal axis of the body. Rotation of the wings 924 may be controlled by a control system 926 sealingly housed within the body 912. To facilitate the rapid removal and reattachment, the wings 924 may be secured to body 912 by a quick-release attachment 930.

FIG. 15 illustrates the control system 926 of FIG. 14 in more detail. In particular, the control system 926 may include a microprocessor-based control circuit 934 having respective inputs 935 to 939 to receive control signals representative of desired depth 935, actual depth 936, desired lateral position 937, actual lateral position 938 and roll angle 939 of the rudder 910. The desired depth signal can be either a fixed signal corresponding to the aforementioned 10 meters, or an adjustable signal, while the actual depth signal is typically produced by a depth sensor 940 mounted in or on the rudder 910. The roll angle signal 939 may be produced by an inclinometer 942 mounted within the rudder 910.

If a riser is made of a less flexible pipe, or an inflexible, rigid pipe it may not assume a compliant shape. In such embodiment, the riser will maintain a substantially rigid shape. In such embodiment, special heave compensation devices may be needed, as will be apparent to those of ordinary skill in the art.

While the inventions have been described in connection with a number of exemplary embodiments, and implementations, the inventions are not so limited, but rather cover various modifications, and equivalent arrangements, which fall within the purview of the appended claims.

Claims

1. A subsea intervention system, comprising:

a) a floating vessel;

b) a source of coiled tubing at the floating vessel;

c) a seabed installation including a wellhead;

d) a compliant guide having first and second ends, said first end being operatively connected to said floating vessel and said second end to operatively connected to said seabed installation, the compliant guide providing a conduit between the floating vessel and the wellhead for the coiled tubing;

e) at least one injector at the floating vessel for pushing the coiled tubing into the compliant guide; and

f) a carousel proximate the wellhead comprising a plurality of chambers with intervention tools in at least two of said chambers.

2. A subsea intervention system, comprising:

a floating vessel;

a source of coiled tubing at the floating vessel;

a seabed installation including a wellhead;

a compliant guide having first and second ends, said first end being operatively connected to said floating vessel and said second end operatively connected to said seabed installation, the compliant guide providing a conduit between the floating vessel and the wellhead for the coiled tubing;

at least one injector at the floating vessel for pushing the coiled tubing into the compliant guide; and

a carousel proximate the wellhead comprising a plurality of chambers with intervention tools in at least two of said chambers,

wherein the system further comprises a plurality of sensing units disposed at spaced intervals along the compliant guide,

wherein the sensing units monitor the radius, pressure, ovality, wall thickness and movements in three-dimensional space of the compliant guide,

wherein the compliant guide includes a rudder assembly for controlling movement of the compliant guide and

the system further includes a filter mechanism disposed between the wellhead and flow line for filtering undesirable solids from the wellhead.

3. The system of claim 2, wherein said intervention tools are selected from the group consisting of bottom hole assemblies, crown plugs and intervention work tools.

4. The system of claim 2, wherein the carousel is operatively connected to the second end of the compliant guide as the compliant guide is lowered to the seabed installation.

5. The system of claim 2, wherein the carousel is operatively connected to and is part of the seabed installation.

6. The system of claim 2, wherein the sensing units function to measure the magnitude and direction of forces acting on the compliant guide and to transmit that information to a vessel response unit located proximate the floating vessel.

7. The system of claim 2, further comprising vessel repositioning apparatus which utilizes the information from the sensors to reposition the floating vessel.

8. The system of claim 2, wherein the rudder assembly includes horizontal rudders and vertical rudders for controlling pitch and angle of the rudders by sensors and a fiber optic line disposed along the complaint guide.

9. The system of claim 2, wherein the rudder assembly is configured to move the complaint guide from a first wellhead to a second wellhead.

10. The system of claim 2, wherein the rudder assembly is used in combination with a buoyancy device, including an air bag.

11. The system of claim 2, wherein the rudder assembly includes a housing having a plurality of opposed control surfaces or wings molded from a fiber-reinforced plastics material, and which project horizontally outwardly from the housing and which are independently rotatable about a common axis extending substantially perpendicularly through a longitudinal axis of the housing.

12. The system of claim 11, wherein rotation of the opposed control surfaces or wings is controlled by a control system housed within the housing.

13. The system of claim 11, wherein the opposed control surfaces or wings are secured to the housing by a quick-release attachment device.

14. The system of claim 13, wherein the control system includes a microprocessor-based control circuit configured to receive control signals representative of desired depth, actual depth, desired lateral position, actual lateral position, and roll angle of the rudder assembly.

15. The system of claim 14, wherein the desired depth signal is a fixed signal corresponding to a predetermined depth, and an actual depth signal is provided by a depth sensor mounted in or on the rudder assembly.

16. The system of claim 14, wherein the desired depth signal is an adjustable signal corresponding to an adjustable depth, and an actual depth signal is provided by a depth sensor mounted in or on the rudder assembly.

17. The system of claim 14, wherein the roll angle signal is provided by an inclinometer mounted in or on the rudder assembly.

18. The system of claim 1 which further comprises a subsea handling system which includes equipment for deploying the compliant guide subsea.

19. The system of claim 18 wherein the subsea handling system includes a heave compensation mechanism.