Patent Application
20140262656
This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present invention, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present invention. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
Oil and natural gas may have a significant effect on modern economies and societies. Indeed, devices and systems that depend on oil and natural gas are ubiquitous. For instance, oil and natural gas are used for fuel in a wide variety of vehicles, such as cars, airplanes, boats, and the like. Further, oil and natural gas are frequently used to heat homes during winter, to generate electricity, and to manufacture a variety of everyday products.
In order to meet the demand for such natural resources, companies often invest significant amounts of time and money in searching for and extracting oil, natural gas, and other subterranean resources from the earth. Particularly, once a desired resource is discovered below the surface of the earth, drilling and production systems are often employed to access and extract the resource. These systems may be located onshore or offshore depending on the location of a desired resource. Offshore systems generally include riser systems useful in attaching surface-based structures to the sea bottom. For example, in a subsea well, the drilling risers may extend from the seafloor up to a rig on the surface of the sea. Risers, including subsea risers, may be subjected to the flow of fluids across their surfaces (both internal and external). The flow of fluids may lead to vibration of the riser, such as vortex-induced vibration. Over time, the vibration can lead to damage and/or failure of the riser.
Various features, aspects, and advantages of the present invention will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:
One or more specific embodiments of the present invention will be described below. These described embodiments are only exemplary of the present invention. Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skills having the benefit of this disclosure.
Certain exemplary embodiments of the present invention include systems and methods for dampening the vibration of risers, and other equipment used in sub-sea resource extraction systems. In particular, the disclosed embodiments include the use of viscoelastic material in combination with a tuned mass damper. More specifically, in certain embodiments, the tuned mass tamper may include a first beam (e.g., L-shaped or angled beam) having a tunable mass, wherein the first beam is coupled to and vibrates with certain riser structures. The tuned mass damper may also include a secure beam having a limiting device (e.g., a ring portion) disposed around a segment of the first beam. Furthermore, a viscoelastic material may be disposed on the segment of the first beam and/or the limiting device of the second beam. As the riser structure vibrates, the first beam with the tunable mass vibrates within the limiting device. As the first and second beams contact one another in the form of impact, the viscoelastic material absorbs the vibrational energy, thereby dampening the vibration in the riser system.
The techniques described herein may also include the use of certain devices and coatings suitable for long-term disposition of a pounding tune mass damper (PTMD) in an undersea environment. For example, filter housings and/or biological growth inhibitors may be used to minimize or eliminate marine growth and other fouling agents. The PTMD may be used in a variety of orientations, including vertical orientations, angled orientations, and horizontal orientations. Further, the PTMD may include passive and/or active tuning techniques, suitable for tuning the PTMD to a variety of riser structures and environmental conditions. It is to be noted that while the embodiments disclosed herein are described in terms of a subsea environment, similar embodiments may be used in above ground surfaces, such as guide wires or cables, bridge support cables, and the like.
With the foregoing in mind and turning now to
The wellhead assembly 12 typically includes multiple components that control and regulate activities and conditions associated with the well 16. For example, the wellhead assembly 12 generally includes bodies, valves and seals that route produced minerals (e.g., hydrocarbons) from the mineral deposit 14, provide for regulating pressure in the well 16, and provide for the injection of chemicals into the well-bore 18 (e.g., down-hole). In the illustrated embodiment, the wellhead assembly 12 may include a tubing spool, a casing spool, and a hanger (e.g., a tubing hanger and/or a casing hanger). The system 10 may include other devices that are coupled to the wellhead assembly 12, such as a blowout preventer (BOP) stack 20 and devices that are used to assemble and control various components of the wellhead assembly 12. For example, in certain embodiments, the BOP stack 20 may include a lower BOP stack 22 and a lower marine riser package (LMRP) 24, which may be coupled by a hydraulically operated connector, such as a riser connector. The BOP stack 20 may include a variety of valves, fittings and controls to block oil, gas, or other fluid from exiting the well in the event of an unintentional release of pressure or an overpressure condition.
A drilling riser 26 including one or more riser joints 27 may extend from the BOP stack 20 to a rig 28, such as a platform or floating vessel. For example, the rig 28 may be positioned above the well 16. The rig 28 may include components suitable for operation of the mineral extraction system 10, such as pumps, tanks, power equipment, and any other components. In the illustrated embodiment, the rig 24 includes a derrick 30 to support the drilling riser 26 during running and retrieval, a tension control mechanism, and other components.
The drilling riser 26 may carry drilling fluid (e.g., “mud) from the rig 28 to the well 16, and may carry the drilling fluid (“returns”), cuttings, or any other substance, from the well 16 to the rig 28. The drilling riser 26 may include a main line having a large diameter and one or more auxiliary lines. The main line may be connected centrally over the bore (such as coaxially) of the well 16, and may provide a passage from the rig 28 to the well 16. The auxiliary lines may include choke lines, kill lines, hydraulic lines, glycol injection, mud return, and/or mud boost lines. For example, some of the auxiliary lines may be coupled to the BOP stack 20 to provide choke and kill functions to the BOP stack 20.
The drilling riser 26 may also include additional components, such as flotation devices, clamps, or other devices distributed along the length of the drilling riser 26. For example, the illustrated drilling riser 26 includes buoyancy cans 31 coupled to an exterior of the drilling riser 26. Specifically, the buoyancy cans 31 are containers, which may be cylindrical, that form an annulus about the exterior of the drilling riser 26 and include chambers, which may be filled with air, low density fluid, or other material. As a result, the buoyancy cans 31 may operate to apply tension (e.g., an upward force) to the drilling riser 26. In this manner, a desired tension in the drilling riser 26 may be maintained. Furthermore, in certain embodiments, the buoyancy cans 31 may be variable or fixed. In other words, certain buoyancy cans 31 (e.g., variable buoyancy cans) may allow injection or removal of air or other fluid in the buoyancy cans 31, thereby adjusting the tension (e.g., upward force) that the buoyancy cans 31 apply to the drilling riser 26. Other buoyancy cans 31 (e.g., fixed buoyancy cans) may not allow for the adjustment of tension (e.g., upward force) applied by the buoyancy cans 31 to the drilling riser 26.
As described further below, the drilling riser 26 may be formed from numerous “joints” of pipe (e.g., riser joints 27), coupled together via flanges, joints, or any other suitable devices or connectors. In the illustrated embodiment, the drilling riser 26 includes multiple joints 32 which couple the drilling riser 26 to various components of the subsea mineral extraction system 10. For example, a flexible joint 34 (e.g., a first flexible joint 36) couples the drilling riser 26 to the rig 28. Additionally, another flexible joint 34 (e.g., a second flexible joint 38) couples the drilling riser 26 to the BOP stack 20. As will be appreciated, the flex joints 34 may be configured to reduce bending stresses in the drilling riser 26. For example, each flex joint 34 may include a ball and socket assembly having a central passage extending through the flex joint 34, through which the drilling fluid and other working fluids may pass.
Furthermore, the drilling riser 26 may include a tensioner or telescopic joint 40. The tensioner 40 is a riser joint that includes inner and outer tubes or barrels, which may move relative to one another. Specifically, the barrels of the telescopic joint 40 may move relative to one another to allow for changes in the length of the drilling riser 26 as the rig 28 moves due to winds, ocean currents, and so forth. Additionally, the telescopic joint 40 may also include a central passage extending through the telescopic joint 40, through which the drilling fluid and other working fluids may pass.
One or more vibration damper systems (e.g. PTMDs) 39 may be disposed at various locations of the resource extraction system 10 and used to minimize vibration, for example, vortex-induced vibration. Vortex-induced vibration is generally caused by currents (e.g., water currents) flowing across structures such as riser pipe and cables. In the illustrated example, currents may flow across the risers 27, anchor cabling 41, and/or anchor cabling 43 attaching, for example, vessel 45 to a seabed. Such currents may lead to vibration. However, as further described herein, the vibration damper systems 39 may minimize or eliminate vibrations, including vortex-induced vibration. As depicted, the vibration damper systems 39 may be disposed at various angles and orientations. For example, any vibration damper system 39 may be disposed at an angle α between 0° to 360° with respect to a vertical axis 44 and/or a horizontal axis 46. Further, multiple vibration damper systems 39 may be disposed on a structure, such as the drilling riser 26, the anchor cabling 41, and/or the anchor cabling 43. Additionally, each vibration damper system 39 may be tuned to a desired frequency, such as a natural frequency and related frequencies (e.g., normal mode frequencies) of a desired riser. By disposing multiple vibration damper systems 39, including vibration damper systems 39 tuned to minimize vibrations at a given frequency, an improved reduction of vibration may be enabled, thus extending the life of certain structures.
Turning to
This vortex-induced vibration and other similar vibrations may lead to increased fatigue of the structures 26, 41, and/or 43 of the resource extraction system 10 over time. In general, the energy magnitude of a given section or portion of the structures 26, 41, and/or 43 may be a function of the frequency of the vortex-induced vibration.
The natural frequency ωn of the portion of one of the structures 26, 41, and/or 43 is the frequency at which that portion vibrates with the largest energy magnitude when set in motion. In actuality, the portion may have multiple natural frequencies ωn (i.e. harmonic frequencies) above the natural frequency ωn illustrated in
In the present embodiment, the vibrational damper system 39 dampens vibrations in the pipe structure 80 (e.g., a portion of the structures 27, 41, or 43) as the first beam 74 vibrates and impacts the viscoelastic material 78 within the second beam 76. The pipe structure 80, as explained above, may be subjected to turbulence by either wind or water that causes the pipe 78 to vibrate. As the pipe 80 vibrates, it causes the first beam 74 and mass 72 to vibrate. In some embodiments, the mass 72 is tuned to enable the first beam 74 to vibrate at the same natural frequency as the pipe structure 80. Thus, as the pipe structure 80 begins to vibrate at a specific frequency, the first beam 74 with the tuned mass 72 will correspondingly vibrate at the same frequency. At specific frequencies (e.g., resonance frequencies), the oscillations of the pipe structure 80 will cause the mass 72 and the first beam 74 to reach amplitudes sufficient for the first beam 74 to impact the second beam 76. The impact of the first beam 74 against the second beam 76 compresses the viscoelastic material 78 between the first beam 74 and the second beam 76. This impact allows the viscoelastic material 78 to absorb vibrational energy and thus dampen the vibrations of the pipe structure 80. In some embodiments, the second beam 76 may have a significant stiffness to reduce the introduction of additional dynamics, to the pipe structure 80, caused by the impact of the first beam 74 against the second beam 76. In this manner, the vibration damper system 39 limits/reduces the vibrational energy in the pipe structure 80.
Viscoelastic material is defined as material that exhibits the property of viscoelasticity. Viscoelastic materials have both viscous and elastic characteristics. Viscous materials resist shear flow and strain linearly with time when a stress is applied. Elastic materials strain instantaneously when stretched and then return to their original state once the stress is removed. Viscoelastic materials exhibit elements of both of these properties, and as such, exhibit time dependent strain. Exemplary viscoelastic materials may include acrylic viscoelastic material, viscoelastic damping polymer. These viscoelastic materials may come in a variety of forms (e.g., tape, spray coating, brush coating, premolded, a solution for dipping, etc.) These different forms facilitate the attachment and placement of the viscoelastic material 78 on the vibration damper system 39. The system 39 may be attached to risers, cables, chains, and so on, using a variety of techniques. For example, the components 82 and 92 may be welded to the structure 80, adhered (e.g., using glues, thermal bonding, and so on), clamped (e.g., hose clamped, screw/band clamped, wire clamped, ear clamped, spring clamped), bolted, screwed in place, or a combination thereof.
In order to limit/reduce vibration in the pipe structure 80, the vibration damping system 39 includes the second beam 76 to limit movement of the first beam 74 and dampen vibration with the viscoelastic material 78. The second beam 76 includes the first portion 92 and the second peripheral end portion 94. The first portion 92 defines an end portion 96 that is coupled to the pipe structure 80 with a connection 98, such as a weld, a flange, a bolt, or a combination thereof. In other embodiments, the second beam 76 may be attached to another structure rather than the pipe structure 80. For instance, only the L-shaped beam 74 may be attached to the pipe structure 80, while the second beam 76 attaches to another structure.
The second portion 94 of the second beam 76 is ring shaped and defines a circular opening 100. In other embodiments, the second portion 94 may define a different shaped opening 100, such as an oval opening, a square opening, a polygonal opening, a rectangular opening, a triangular opening, or any other shape. Alternatively the second portion 94 may define a non-continuous opening 100, e.g., one or more limiting structures above, below, left, and/or right of the first beam 74. The opening 100 surrounds a segment 102 of the first beam 74, and defines a limited range of movement of the segment 102 within the opening 100. For example, the opening 100 defines upper and lower ranges of movement 101 and 103 and left and right ranges of movement (i.e., in and out of the page). As mentioned above, as the pipe structure 80 vibrates in response to wind, water flow, or other drivers, the mass 72 and first beam 74 may corresponding begin to vibrate. Once the first beam 74 reaches a specific amplitude, the segment 102 contacts the viscoelastic material 78 disposed around the opening 100. The viscoelastic material 78 is therefore able to absorb vibrational energy from the pipe structure 80 by contact with the segment 102 of the first beam 74. As discussed above, the second beam 76 may have a significant stiffness and therefore may not emit a large vibrational response from the impact of the first beam 74 within the ring portion 94. In this way, the stiffness of the second beam 76 aids the viscoelastic material 78 in damping vibration in the pipe structure 80.
As discussed above, the opening 100 of the second beam 76 may have a variety of shapes to control dampening in various directions. For instance, if more damping is desired in a specific direction due to the design of the pipe structure, then the opening 100 may define a different shape that reduces vibration in certain directions while allowing more in others. For example, the opening 100 could be oval or rectangular in shape. These shapes may allow greater oscillations in one direction while reducing them in another. In still other embodiments, the viscoelastic material 78 thickness may be increased in designated locations of the opening 100 or on the first beam 74. The increased thickness may reduce vibrations in certain directions or compensate for viscoelastic material 78 wear by more frequent impact in known locations.
In the depicted embodiment, the housing 140 is a square housing 140 including six walls 142, 144, 146, 148, 150, and 152. In one embodiment, the walls 142, 144, 146, 148, 150, and 152 are mesh walls that enable fluid (e.g., saltwater) to flow through but block detritus, debris, and biological organisms (e.g., barnacles) from growing and/or interfering with operations of the components 72, 74, 76, 78, 82, 84, 92, 94. In another embodiment, the walls 142, 144, 146, 148, 150, and 152 are solid walls and the components 72, 74, 76, 78, 82, 84, 92, 94 may be immersed in a biological growth-inhibitor fluid. The solid walls 142, 144, 146, 148, 150, and 152 may contain the biological growth-inhibitor fluid but block outside fluid (e.g., saltwater) from entering the housing 140. In another embodiment, the components 72, 74, 76, 78, 82, 84, 92, 94 may be coated with a gel or coating that inhibits biological growth. Accordingly, the components 72, 74, 76, 78, 82, 84, 92, 94 may be better protected against interference during operations caused by marine organisms and/or detritus.
Also depicted is a vibration sensor 166 communicatively coupled to the controller 160 through a conduit 168. The controller 160 may receive signals from the sensor 166 representative of a vibration. The controller 160 may use the signals to derive, for example, the natural frequency ωn of the portion of the structure 27, 41, and/or 43 having the depicted cable or tube 80. The controller 160 may then extend or retract the beam 84 by using the beam extender, thus fine tuning the dampening of vibrational energy. For example, extending the beam 84 may increase the amplitude response of the member 74, and decreasing the length of the beam 84 may decrease the amplitude response of the member 74. Additionally or alternatively, the mass 72 may be replaced in situ, for example by using a human diver or remotely operated underwater vehicle, to accommodate a variety of conditions. In this manner, the vibration damper system 39 may be fine-tuned to respond to a variety of conditions.
It is to be noted that, while the depicted embodiment shows the platform 170 tethered to the sea bottom by using a variety of risers 172, 174, 178, 182, and tendons 176, in other embodiments, the platform 170 may use a subset of the risers 172, 174, 178, 182, and/or tendons 176, depending, for example, on the type of the platform 170. For example, in embodiments where the platform 170 is a fixed platform or a compliant tower platform, then the risers 172, 174, 178, 182 may be used while the tendons 176 may not be used. Likewise, if the platform 170 is a sea star platform, a floating production system, a tension leg platform, or a spar platform, then the risers 172, 174, 178, 182 may be used along with the tendons 176.
While the invention may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the invention is not intended to be limited to the particular forms disclosed. Rather, the invention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims.
This application is related to U.S. patent application Ser. No. 12/917,456, entitled “POUNDING TUNE MASS DAMPER WITH VISCOELASTIC MATERIAL”, filed Nov. 1, 2010, which is herein incorporated by reference.
