KR20180008508A - Exercise compensation for drilling pipe - Google Patents

Abstract

A system and method for performing drill pipe motion compensation is disclosed. The system includes a drill pipe and a marine riser pipe, and the marine riser pipe can be configured to support the weight of the drill pipe. The pipe holder may be coupled to the drill pipe and the marine riser pipe, and may be configured to suspend the drill pipe on the marine riser pipe. The drill pipe support system can be coupled to pipe holders and marine riser pipes. The drill pipe support system can be configured to deliver the weight of the drill pipe along with the pipe holder to the marine riser pipe. The system may also include a plurality of wires coupled to the marine riser pipe. The one or more tensioners may be configured to compensate for motion on the drilling pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe.

Description

Exercise compensation for drilling pipe

Cross reference of related applications

This application claims priority to U.S. Provisional Patent Application No. 62 / 150,725, filed April 21, 2015 entitled " Exercise Compensation for Drilling Pipe ", incorporated herein by reference, by Edward Peter Kenneth Bourgeau et al.

The present invention relates to a method and system for performing drill pipe motion compensation. More particularly, the present invention relates to a method and system for performing drill pipe motion compensation with marine riser tensioning systems.

Drilling pipes used for offshore drilling are often tested for a variety of reasons. For example, after the well has been drilled and casing, the drill pipe can be tested as part of the Drill Stem Test (DST) to inspect the pressure, permeability, and production capacity of the formation. Testing also helps determine whether the oil has found a commercially viable hydrocarbon layer. During DST, the piping connected to the connected drilling pipe and / or drilling pipe must remain stationary with respect to the well. It is necessary to compensate for the movement of the ship in the load path that supports the drill string, because the rig or the vessel that supports the drill pipe is floating. DST can take several months to complete, and the compensation system must operate reliably during the test period. Failure of the compensation system may damage the equipment, lead to the activation of emergency response measures, may require a restart of the DST, and this can take considerable time.

Typically, several techniques are used in the industry to compensate for ship motion, all of which involve a dedicated compensation system in the load path that supports the drill string. One prior art technique involves using well drilling equipment to take out the cable supporting the drilling pipe or piping in synchronism with ship movement. This technique is often referred to as active compensation because of the active use of power to move the well drilling rig. Another prior art technique involves the use of a hydraulic piston which is pressurized by a large gas reservoir, which maintains a constant tension in the drill pipe or piping. Such a system, sometimes referred to as a drill string compensator, is mounted in a derrick and is supported by a well drilling rig drive block. Still another conventional technique involves using a hydraulic piston which is pressurized by a large gas reservoir in a special frame specially designed to support the piping used during the DST. This technique is referred to as CCTLF (Compensating Coil Tubing Lift Frame).

There are many drawbacks associated with the prior art techniques described above. For example, in active compensation techniques and drill string compensation techniques, well drilling rigs can affect DST because well drilling rigs are used to implement the compensation system. In addition, in CCTLF technology, special frames must be mounted on the vessel to implement the compensation system.

The drilling pipe motion compensation is achieved by compensating the weight of the drilling pipe with a marine riser pipe and by compensating the movement in the drilling pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe, Can be performed without the inherent drawbacks of the compensation system. In particular, according to one embodiment, a method of performing drilling pipe motion compensation includes supporting a weight of a drilling pipe with a marine riser pipe. Depending on the embodiment, the marine riser pipe may be coupled to a well head on the sea bed. In some embodiments, supporting the weight of the drilling pipe with the marine riser pipe may include suspending the drilling pipe on the marine riser pipe with the pipe holder. The step of supporting the weight of the drilling pipe with the marine riser pipe may also include the step of conveying the weight of the drilling pipe to the marine riser pipe. According to an embodiment, the step of delivering the weight of the drill pipe to the marine riser pipe comprises mechanically coupling the pipe holder and the marine riser pipe to the drill pipe support system, wherein the drill pipe support system and the pipe holder comprise And to deliver the weight to the marine riser pipe.

The method may also include compensating for motion on the drilling pipe by controlling the tension of one or more of the plurality of wires coupled to the marine riser pipe. In some embodiments, controlling the tension in one or more of the plurality of wires may include maintaining a constant tension in one or more of the plurality of wires.

In some embodiments, the method may further include detecting a load on the drilling pipe or a signal indicative of the tension in one or more of the plurality of wires. According to an embodiment, controlling the tension in one or more of the plurality of wires may comprise adjusting the tension in one or more of the plurality of wires in response to sensing the signal.

According to an embodiment, the method may also comprise constituting a plurality of wires to collectively hold the weight of both the marine riser pipe and the drilling pipe. In addition, in an embodiment, for each of one or more of the plurality of wires, the tension may be controlled by one of a hydro-pneumatic tensioner and an electric tensioner. In some embodiments, the method may also include coupling a flexible tube to the drilling pipe, wherein the flexible tube receives the movement of the vessel and reduces the amount of movement experienced by the drilling pipe relative to vessel movement It bends.

According to another embodiment, the apparatus comprises: a drilling pipe; A marine riser pipe configured to support the weight of the drilling pipe; A plurality of wires coupled to the marine riser pipe; And at least one tensioner configured to compensate for motion in the drill pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe. The apparatus may further comprise a pipe holder configured to suspend the drilling pipe on the marine riser pipe and suspending the drilling pipe on the marine riser pipe causes the marine riser pipe to support the weight of the drilling pipe. The apparatus may further include a drill pipe support system coupled to the pipe holder and the marine riser pipe, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe do. According to an embodiment, controlling the tension in one or more of the plurality of wires includes maintaining a constant tension in one or more of the plurality of wires.

In some embodiments, the apparatus also includes one or more sensors coupled to the marine riser pipe and configured to sense signals indicative of the load on the drilling pipe or the tension in one or more of the plurality of wires. In one embodiment, the at least one sensor comprises at least one of an accelerometer and a load cell. The tensioners may be configured to adjust the tension of the fish in one or more of the plurality of wires in response to sensing of the signals. According to an embodiment, each of the one or more tensioners may be one of a pneumatic tensioner and an electric tensioner. In another embodiment, the plurality of wires are configured to collectively hold the weight of both the ocean riser pipe and the drill pipe, and the marine riser pipe is coupled to the submergence release device. According to some embodiments, the apparatus also includes a flexible tube coupled to the drilling pipe, wherein the flexible tube receives the vessel movement and is bent to reduce the amount of movement experienced by the drilling pipe relative to vessel movement.

According to yet another embodiment, the apparatus includes a pipe holder coupled to a drilling pipe and a marine riser pipe. The pipe holder may be configured to suspend the drilling pipe on the marine riser pipe. The apparatus also includes a drill pipe support system coupled to the pipe holder and the marine riser pipe, wherein the drill pipe support system and the pipe holder are configured to deliver the weight of the drill pipe to the marine riser pipe.

As used herein, the term "blowout preventer" may include, but is not limited to, a single blowout protector, as well as more than one blowout protector (e.g., a blowout protector stack) Do not.

The term "coupled" is defined as being connected, although not necessarily directly, and not necessarily mechanically; The two articles "combined " can be integrated with each other. The singular terms are defined as one or more unless the context clearly dictates otherwise. The term "substantially" is defined as (and includes) what is specified, and not necessarily completely specified, as understood by those skilled in the art; for example, substantially 90 [deg.] Includes 90 [deg.], Lt; / RTI > includes parallel). In any of the disclosed embodiments, the terms " substantially ", "approximately ", and" about "mean " within a specified percentage [percent]" if the percentage includes 0.1%, 1%, 5%, 10% and 20% Can be replaced with " with "

Also, a device or system configured in a particular manner is configured in at least that way, but may also be configured in other ways than the manner specifically described.

(And any form such as "including"), "having" (and any form such as "having"), "having" And "accept" (and any form such as "accepting") are unbounded verbs. As a result, a device that "comprises," " comprises, "comprises, or" contains " more than one element retains such one or more elements, but is not limited to possessing only such elements. Likewise, a "including," "having," "having", or "containing" one or more steps has one or more steps, but is not limited to having only such one or more steps.

The foregoing has outlined rather broadly certain features and technical advantages of embodiments of the present invention in order that the following detailed description may be better understood. Additional features and advantages forming the gist of the claims of the present invention will be described hereinafter. It should be understood by those skilled in the art that the disclosed concepts and specific embodiments may be readily utilized as a basis for modifying or designing other structures for carrying out the same or similar purposes. It should also be understood by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims. Additional features will be better understood from the following description when considered in connection with the accompanying drawings. It is to be expressly understood, however, that each drawing is provided for the purposes of illustration and description only and is not intended to limit the invention.

BRIEF DESCRIPTION OF THE DRAWINGS For a more complete understanding of the disclosed systems and methods, reference is now made to the following description taken in connection with the accompanying drawings, In the accompanying drawings, like components or features may have the same reference numerals. Furthermore, various components of the same type can be distinguished by reference numerals having second reference numerals that distinguish similar components. When the first reference numerals are used in the specification, any one or more similar components having the same first reference numerals regardless of the second reference numerals are applicable.
BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1A is a block diagram illustrating a drill pipe motion compensating system in accordance with an embodiment of the present invention. FIG.
FIG. 1B is a block diagram illustrating a first side view of the drill pipe motion compensation system shown in FIG. 1A according to one embodiment of the present invention. FIG.
FIG. 1C is a block diagram illustrating a second side view of the drill pipe motion compensation system shown in FIG. 1A according to one embodiment of the present invention. FIG.
2 is a flow chart illustrating a method of performing drill pipe motion compensation in accordance with one embodiment of the present invention.

The drilling pipe motion compensation system is designed to compensate for the weight of the drilling pipe in a marine riser pipe that is fixed to the seabed at the bottom and fixed to the drilling rig / vessel at the top, through a system that compensates for ship motion, such as a marine riser tension system or a marine riser system . ≪ / RTI > The marine riser pipe, and the marine motion compensation system of the drilling pipe motion compensating system, which compensates for the motion of the drilling pipe supported by the marine riser pipe, is configured to control the tension in one or more of the plurality of wires coupled to the marine riser pipe Lt; / RTI > The drill pipe motion compensation system disclosed herein can show many advantages over conventional drill pipe motion compensation systems. For example, the drill pipe motion compensating system disclosed herein can place the load of the drill string at a lower center of gravity, thus improving ship stability. In addition, since the drilling pipe is suspended on the marine riser, the drilling pipe motion compensation system disclosed herein can utilize a well drilling rig to manage other activities such as making pipes or other inventory management problems. Moreover, the drill pipe motion compensation system disclosed herein can use a reliable and existing compensation system that is continuously used during drilling.

FIG. 1A is a block diagram illustrating a drill pipe motion compensation system in accordance with an embodiment of the present invention. 1B and 1C also provide a side view of the drill pipe motion compensation system shown in FIG. 1A. The drilling pipe motion compensation system 100 may include a drilling pipe 102, and a marine riser pipe 104. As used herein, a pipe may refer to a single pipe or a string of pipes coupled together, for example, the strings of pipes are coupled together to function as a single pipe.

The marine riser pipe 104 may be configured to support the weight of the drilling pipe 102. For example, the system 100 may include a pipe holder 106 and a drill pipe support system 114 to assist the marine riser pipe 104 to support the weight of the drill pipe 102. As shown in Fig. 1A, the drill pipe 102 can be inserted into the pipe holder 106. Fig. Depending on the embodiment, the pipe holder 106 may be configured to suspend the drilling pipe 102 on the marine riser pipe 104. Suspension of the drilling pipe 102 on the marine riser pipe 104 by the pipe holder 106 may allow the marine riser pipe 104 to support the weight of the drilling pipe 102. In addition, configuring the pipe holder 106 to suspend the drilling pipe 102 on the marine riser pipe 104 can also be accomplished by placing the drilling pipe 102 in a substantially stationary condition relative to the ejection- The pipe holder 106 may also be configured to couple the drilling pipe 102 to the marine riser pipe 104 to maintain the pipe. In particular, suspending the drill pipe 102 on the marine riser pipe 104, because the marine riser pipe 104 is kept substantially stationary relative to the ejection protection device 180, But also to remain substantially stationary relative to the ejection blocking device 180. [ Although the pipe holder 106 is shown as a cylindrical pipe that horizontally surrounds the drill pipe 102, those skilled in the art will appreciate that the pipe holder 106 may be any suitable one, as long as it performs all the functions of the pipe holder 106, As will be appreciated by those skilled in the art.

The drill pipe support system 114 may provide additional support for the pipe holder 106 as it floats the drill pipe 102 on the marine riser pipe 104. The drill pipe support system 114 may also help deliver the weight of the drill pipe 102 to the marine riser pipe 104. In one embodiment, such as the embodiment shown in FIG. 1, the drill pipe support system 114 may include beams 114A-114D. However, those skilled in the art will appreciate that drill pipe support system 114 may be implemented with a support system other than a beam support system, and so long as the support systems, either directly or indirectly, support the operation of the drill pipe support system as disclosed herein, It will be readily appreciated that the invention as described in the appended claims is not limited to beam support systems.

The drill pipe support system may be mechanically coupled to the pipe holder 106 and the marine riser pipe 104. For example, in one embodiment, such as the embodiment shown in FIG. 1, beams 114A-114D may be mechanically coupled to pipe holder 106 and marine riser pipe 104. In one embodiment, the beam supports 114A-114D may be coupled directly to the marine riser pipe 104. In other embodiments, the beam supports 114A-114D may be coupled to the marine riser pipe 104 by coupling to a tension ring 116 coupled to the marine riser pipe 104.

The drill pipe support system 114 may be configured to communicate the weight of the drill pipe 102 with the pipe holder 106 to the marine riser pipe 104. For example, as shown in the embodiment shown in FIG. 1, the beam supports 114A-114D may be configured to communicate the weight of the drill pipe 102 with the pipe holder 106 to the marine riser pipe 104 . In one embodiment, when the drilling pipe 102 is lowered through the pipe holder 106, the pipe holder 106, and the beam supports 114A-114D connected to the marine riser pipe 104, And from the drill pipe 102 supported by the beams 114A-114D to the marine riser pipe 104. The loads on both the marine riser pipe 104 and the supported drilling pipe 102 are then transferred from the marine riser pipe 104 to the ship via the tension ring 116 coupled to the marine riser pipe 104, 110D to the tension wires 108A-108D connected to the ship. For example, as shown in FIG. 1, the tension ring 116 may be coupled to the marine riser pipe 104 and may include a plurality of wire hooks 120A-120D. In some embodiments, the tension ring 116 may be a ring-shaped load bearing device coupled to the marine riser pipe 104. By combining the plurality of wires 108A-108D on the plurality of wire hooks 120A-120D on the tension ring 116, the weight of the drilling pipe 102 and the marine riser pipe 104 is greater than the weight of the plurality of wires 108A- -108D to the ship structure where the tensioners 110 are located.

The system 100 also includes a plurality of wires 108A-108D coupled to the marine riser pipe 104, and one or more tensioners 110A-110D. A plurality of wires 108A-108D may be coupled to the marine riser pipe 104 by engaging a tension ring 116 coupled to the marine riser pipe 104, as shown in FIG. For example, the tension ring 116 coupled to the marine riser pipe 104 may include a plurality of hooks 120A-120D. Each of the plurality of wires 108A-108D may be connected to the marine riser pipe 104 by coupling to at least one of the plurality of wire hooks 120A-120D. As shown in FIG. 1, a plurality of wires 108 may be coupled to the plurality of hooks 120 through turn-down sheaves 170 from one or more tensioners 110. In particular, a plurality of wires 108A-108D can be coupled to the wire hooks 120A-120D from the tensioners 110A-110D through the turn-down sheaves 170A-170D. In some embodiments, turn-down sheaves 170A-170D can be coupled to ship structure 112 coupled to the vessel on which tensioners 110A-110D are located.

According to some embodiments, the plurality of wires 108 collectively hold and support the weight of both the marine riser pipe 104 and the drilling pipe 102 and maintain and change the tension in the marine riser pipe 104 . In addition, each of the plurality of wires 108 may be mechanically coupled to a separate tensioner 110. Each of the one or more tensioners 110 may be coupled to the vessel structure 112. The ship structure 112 may be a structure that is secured to a ship on which the system 100 is located. In one embodiment, the ship structure 112 can move with the ship to undergo substantially the same ship movement as the ship itself.

In accordance with some embodiments, one or more tensioners 110 may be configured to compensate for motion on the drill pipe 102 by controlling the tension in one or more of the plurality of wires 108 coupled to the marine riser pipe 104 Lt; / RTI > For example, one or more tensioners 108 may control the tension of one or more of the plurality of wires 108 to maintain a constant tension on one or more of the plurality of wires 108. In some embodiments, the control of the tension in one of the plurality of wires 108 may comprise adjusting the length of the wire 108 by the tensioner 110.

In certain embodiments, the tensioner may be a pneumatic tensioner or an electric tensioner. Thus, one or more tensioners 110 may comprise a combination of one or more electric tensioners and one or more oil-air pressure tensioners. For example, in the embodiment shown in FIG. 1A, the tensioners 110A and 110C are electrical tensioners, while the tensioners 110B and 110D are pneumatic tensioners. In other embodiments, the one or more tensioners 110 may be entirely of a pneumatic tensioner. In yet another embodiment, one or more tensioners 110 may be entirely of electrical tensioners.

In some embodiments, one or more tensioners 110, which may include a plurality of wires 108, and a combination of one or more electrical tensioners and one or more pneumatic tensioners, may be operated together as part of a riser tensioning system. A riser tension system including a plurality of wires 108 and a tensioner 110 may include a controller. The controller may be coupled to the tensioner 110 and configured to control the tensioners 110 to control the tension in one or more of the plurality of wires 108. The controller, the at least one tensioner 110, and the plurality of wires 108 may function as a riser tensioning system, such as the improved riser control system disclosed in U.S. Patent Application No. 13 / 715,412, incorporated herein by reference. . As described above, the plurality of wires 108 can be configured to collectively hold and support the weight of the marine riser pipe 104 and the drilling pipe 102. Thus, a riser tensioning system including a tensioner 110 and a plurality of wires 108 can be configured to support the weight of both the marine riser pipe 104 and the drilling pipe 102.

The system 100 also includes one or more sensors 160. In some embodiments, one or more sensors 160 may be coupled to the marine riser pipe 104. For example, in one embodiment, one or more sensors 160 may be coupled directly to a marine riser pipe 104, or to a tension ring 116 coupled to a marine riser pipe 104. In other embodiments, the sensors 160 may be coupled to at least one of the marine riser pipe 104, drilling pipe 102, and pipe holder 106. The sensors 160 may include at least one of an accelerometer and a load cell. In some embodiments, the sensors 160 may measure the tension on one or more of the loads on the drilling pipe 102, or the plurality of wires 108 supporting the marine riser pipe 104 and the weight of the drilling pipe 102 To sense a signal indicative thereof. For example, the sensors 160 may include one or more accelerometers to sense vibrations on the marine riser pipe 104 and / or to detect whether the marine riser pipe 104 is disconnected. In addition, the sensors 160 may also include one or more load cells that sense the tension in the plurality of wires 108. Thus, in some embodiments, the one or more tensioners 110 may be configured to adjust the tension in one or more of the plurality of wires 108 in response to sensing of the signals by the sensors 160. For example, the riser tension system portion of system 100, such as the improved riser control system disclosed in U.S. Patent Application No. 13 / 715,412, is coupled to sensors 160 and processes signals from sensor 160 And may comprise a configured controller. The controller may be configured to process signals from the sensors 160. Based on the processing of the signals received by the sensors, a controller coupled to the one or more tensioners 110 may be coupled to one or more of the plurality of wires 108 in response to sensing of the signals by the sensors 160 One or more tensioners 110 may be controlled to adjust the tension.

Depending on the embodiment, controlling the tension in one or more of the plurality of wires 108 may be desirable, for example, when the marine riser pipe 104 vibrates or when the marine riser pipe 104 is separated from the drilling floor Includes varying the tension in one or more of the plurality of wires (108) in response to a signal from the accelerometer sensor (160). In another embodiment, in response to a signal from the load cell sensor 160 measuring the tension on the wire 108 to determine the weight of the drilling pipe 102 on, for example, the marine riser pipe 104, (110) can be adjusted as the drilling pipe load is applied.

According to some embodiments, the system 100 also includes a flexible tube 130 coupled to the drilling pipe 102. The flexible tube 130 may also be coupled to the vessel where the system 100 is located. In some embodiments, the flexible tube 130 may be configured to be able to bend to receive ship motion. The flexible tube 130 may also be configured to flex to reduce the amount of movement experienced by the drilling pipe 102 relative to vessel motion. In some embodiments, the system 100 may include a valve manifold 150 that may be configured to couple the flexible tube 130 to the drill pipe 102. The system 100 also includes a second flexible tube 140 coupled to the pipe holder 106 and configured to enable the mud to return from the marine riser annulus.

As shown in FIG. 1, the ejection protection device 180 may be surrounded by a blowout protector (BOP) 182. In addition, the BOP 182 may be coupled to a lower marine riser package (LMRP) 184. The marine riser pipe 104 may be configured to couple to the BOP 182 and / or the LMRP 184 in addition to the spill prevention device 180. In particular, in some embodiments, the lower end of the marine riser pipe 104 may be pinned to the seabed 190 to prevent it from moving relative to the well 180. Additionally, the top of the marine riser pipe 104 can be controlled through the tensioners so that it does not move vertically relative to the seabed 190.

In view of the system shown and described herein, the methodology that may be implemented in accordance with the disclosed subject matter will be better understood with reference to various functional block diagrams. While the methodology is shown and described as a series of acts / blocks for purposes of simplicity of explanation, it is to be understood that the claimed subject matter may be practiced simultaneously with other blocks, But are not limited by the number or order of blocks as such. Moreover, not all illustrated blocks may be required to implement the methods described herein. It should be understood that the functionality associated with the blocks may be implemented by software, hardware, combinations thereof, or any other suitable means (e.g., a device, system, process, or component). Additionally, it should also be appreciated that the methodologies disclosed throughout this disclosure may be stored on an article of manufacture to facilitate transferring and transferring such methodologies to a variety of devices. Those skilled in the art will understand and appreciate that the methodology could alternatively be represented as a series of correlated states or events as in the state diagram.

2 is a flow chart illustrating a method of performing drill pipe motion compensation in accordance with an embodiment of the present invention. The method 200 may be implemented with the system described with respect to Figs. 1A-1C. The method 200 includes supporting the weight of the drilling pipe with a marine riser pipe at block 202. Depending on the embodiment, the marine riser pipe may be coupled to a submerged spill prevention device. In some embodiments, supporting the weight of the drilling pipe with the marine riser pipe may include suspending the drilling pipe on the marine riser pipe with the pipe holder. The step of supporting the weight of the drilling pipe with the marine riser pipe may also include the step of conveying the weight of the drilling pipe to the marine riser pipe. According to an embodiment, the step of delivering the weight of the drill pipe to the marine riser pipe may comprise mechanically coupling the drill pipe support system to the pipe holder and the marine riser pipe, wherein the drill pipe support system and pipe holder are drilled And to deliver the weight of the pipe to the marine riser pipe.

At block 204, the method 200 includes compensating for motion on the drilling pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe. In some embodiments, controlling the tension in one or more of the plurality of wires may include maintaining a constant tension in one or more of the plurality of wires.

In some embodiments, a method of performing drill pipe motion compensation may also include sensing a load on the drilling pipe or signals indicative of a tension in one or more of the plurality of wires. According to an embodiment, controlling the tension in one or more of the plurality of wires may include adjusting the tension in one or more of the plurality of wires in response to sensing the signal.

According to an embodiment, a method of performing motion compensation may also comprise constructing a plurality of wires to collectively hold and support the weight of both the marine riser pipe and the drill pipe. In addition, in an embodiment, for each of one or more of the plurality of wires, the tension may be controlled by one of a pneumatic tensioner and an electric tensioner. In some embodiments, a method of performing drilling pipe motion compensation may also include coupling a flexible tube to a drilling pipe, wherein the flexible tube receives a movement of the vessel and includes a movement To reduce the amount of heat.

The schematic flow diagram of FIG. 2 is generally presented as a logical flow diagram. Thus, the cited order and labeled steps represent aspects of the disclosed method. Other steps and methods that are equivalent in function, logic, or effect to one or more steps of the illustrated method, or portions thereof, may be contemplated. In addition, the forms and symbols utilized are provided to illustrate the logical steps of the method, and are not to be construed as limiting the scope of the methods. Although various arrow shapes and line shapes may be used in the flow diagrams, these are understood to not limit the scope of the corresponding method. Indeed, some arrows or other connectors may be used to display only the logical flow of the method. For example, an arrow may indicate an unspecific period of waiting or monitoring period between the listed steps of the depicted method. Additionally, the order in which a particular method occurs may be strictly adhered to or not in accordance with the sequence of corresponding response steps shown.

Although the embodiments disclosed herein have been described with reference to a number of specific details, those skilled in the art will appreciate that embodiments of the invention may be embodied in other specific forms without departing from the spirit of the embodiments of the invention. Therefore, those skilled in the art will appreciate that the embodiments described herein are not to be limited by the exemplary details set forth above, but rather by the appended claims.

While the invention and its representative advantages have been described in detail, it should be understood that various changes, substitutions and alterations can be made therein without departing from the spirit and scope of the invention as defined by the appended claims. Moreover, the scope of the present application is not intended to be limited to the specific embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described herein. A person of ordinary skill in the art will readily appreciate that there is a need for a process, machine, manufacture, or article of manufacture that will presently or later develop substantially the same function or substantially achieve the same result as the corresponding embodiments described herein may be utilized. Compositions, means, methods, or steps will be readily apparent from the present invention. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, composition of matter, means, methods or steps.

Claims (23)

A method for performing drill pipe motion compensation,
Supporting the weight of the drilling pipe with a marine riser pipe; And
And compensating for movement on the drilling pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe. The method of claim 1, wherein supporting the weight of the drilling pipe with the marine riser pipe comprises suspending the drilling pipe on the marine riser pipe with a pipe holder. 3. The method of claim 2, wherein supporting the weight of the drilling pipe with the marine riser pipe comprises delivering the weight of the drilling pipe to the marine riser pipe. 4. The method of claim 3, wherein transferring the weight of the drill pipe to the marine riser pipe comprises mechanically coupling the drill pipe support system to the pipe holder and the marine riser pipe, Wherein the pipe holder is configured to transfer the weight of the drilling pipe to the marine riser pipe. 2. The method of claim 1, wherein controlling the tension of one or more of the plurality of wires comprises maintaining a constant tension in one or more of the plurality of wires. The method of claim 1, further comprising sensing signals indicative of a load on the drilling pipe or a tension on one or more of the plurality of wires. 7. The method of claim 6, wherein controlling the tension in one or more of the plurality of wires comprises adjusting tension in one or more of the plurality of wires in response to sensing the signals. The method of claim 1, wherein for each of the one or more wires of the plurality of wires, the tension is controlled by one of an oil-pneumatic tensioner and an electric tensioner. The method of claim 1, further comprising constructing a plurality of wires to collectively hold the weight of both the marine riser pipe and the drill pipe. The method of claim 1, further comprising coupling a flexible tube to the drilling pipe, the flexible tube receiving the movement of the vessel and reducing the amount of movement experienced by the drilling pipe relative to the vessel movement How to bend. The method of claim 1, wherein the marine riser pipe is coupled to a well head on a submarine. Drilling pipe;
A marine riser pipe configured to support the weight of the drilling pipe;
A plurality of wires coupled to the marine riser pipe; And
And at least one tensioner configured to compensate for movement in the drilling pipe by controlling the tension in one or more of the plurality of wires coupled to the marine riser pipe. 13. The method of claim 12, further comprising a pipe holder configured to suspend the drilling pipe on the marine riser pipe, wherein suspending the drilling pipe on the marine riser pipe comprises: . 14. The system of claim 13, further comprising a drill pipe support system coupled to the pipe holder and the marine riser pipe, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe The device to be configured. 13. The apparatus of claim 12, wherein controlling tension in one or more of the plurality of wires comprises maintaining a constant tension in at least one of the plurality of wires. 13. The apparatus of claim 12, further comprising one or more sensors coupled to the marine riser pipe and configured to sense signals indicative of a load on the drilling pipe or a tension on one or more of the plurality of wires. 17. The apparatus of claim 16, wherein the at least one sensor comprises at least one of an accelerometer and a load cell. 17. The apparatus of claim 16, wherein the tensioners are configured to adjust tension in one or more of the plurality of wires in response to sensing of signals. 13. The apparatus of claim 12, wherein each of the one or more tensioners comprises one of a pneumatic tensioner and an electrical tensioner. 13. The apparatus of claim 12, wherein the plurality of wires are configured to collectively hold the weight of both the marine riser pipe and the drill pipe, wherein the marine riser pipe is coupled to a submerged spill prevention device. 13. The apparatus of claim 12, further comprising a flexible tube coupled to the drill pipe, the flexible tube being adapted to receive a movement of the vessel and to bend the drill pipe in order to reduce the amount of movement experienced by the drill pipe relative to the vessel movement. Lt; / RTI > And a pipe holder coupled to the drill pipe and the marine riser pipe and configured to suspend the drill pipe on the marine riser pipe. 23. The apparatus of claim 22, further comprising a drill pipe support system coupled to the pipe holder and the marine riser pipe,
Wherein the drill pipe support system and the pipe holder are configured to deliver the weight of the drill pipe to the marine riser pipe.

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