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    • 专利摘要:
    PROTECTION PACKAGING, SYSTEM AND METHOD OF PROTECTING UNDERWATER WELLS. A submerged well protection method and equipment adapted to protect a submerged well in the event of a perceived explosion in a way to mitigate environmental damage and physical damage to the submerged wellhead equipment to promote the ability to reconnect and recover control from the well. The protection set is adapted to connect the rising naval tube to the stack of BOPs. In accordance with a protection sequence, the well tube is fixed in the upper and lower protection assemblies and the tube is then sheared between the locations in which it was fixed. Subsequently, an ejection device is activated to physically separate the upper protection assembly and connected upward tube from the lower protection assembly that is connected to the explosion protection stack.
    公开号:BR112013004677B1
    申请号:R112013004677-5
    申请日:2011-08-29
    公开日:2021-03-16
    发明作者:Charles Don Coppedge；Dana Karl Kelley；Charles Porter；Hildebrand Argie Rumann
    申请人:Bastion Technologies, Inc；
    IPC主号:
    专利说明:

    FUNDAMENTALS
    [001] This section provides information on fundamentals to facilitate a better understanding of the various aspects of the invention. It should be understood that the statements in this section of this document should be read from this perspective, and not as acknowledgments of the state of the art.
    [002] The invention relates in general to drilling well maneuvers and, more specifically, to safety devices and methods to seal, control and monitor submerged oil and gas wells. An explosion protector is a specialized large valve used to seal, control and monitor submerged oil and gas wells. Explosion protectors are designed to handle extreme erratic pressures and uncontrolled flow (formation backward) emanating from a well reservoir during drilling. Setbacks can lead to the uncontrolled release of oil and / or gas from a well, resulting in a potentially dangerous submerged well event known as an explosion. Explosion protectors are critical for the safety of the technical team, platform (the equipment used to drill a drilling well) and the environment, and for monitoring and maintaining the well's integrity. Although explosion protectors are intended to be fail-safe devices, accidents can still occur if explosion protectors do not operate properly. For example, during the Deepwater Horizon drilling rig explosion on April 20, 2010, it is believed that explosion protectors were not properly operated and / or were not activated in a timely manner. In addition, due to the failure, the wellhead equipment has been damaged, creating additional obstacles to regaining control of the well. SUMMARY
    [003] According to one or more aspects of the invention, a submerged well protection package for installation on a pile of explosion protectors in a submerged well comprises a protection set connector that interconnects a lower set and an upper set of protection, the protective set connector operable to a disconnected position, where the lower protection set is adapted to be connected to a stack of explosion protectors over a submerged well and the upper protection set is adapted to be connected to a pipe ascending naval; the lower assembly comprising lower wedges for engaging a tube suspended in a hole formed through the lower and upper protection assemblies; the upper protective package comprising upper operable wedges for engaging the tube; and a blade positioned between the upper wedges and the lower wedges, the blade operable for shearing the tube.
    [004] A submerged well protection system according to one or more aspects of the invention comprises a protection set comprising a lower protection set connected to a stack of explosion protectors connected to a submerged well and an upper protection set connected to an ascending naval tube; a protection set connector interconnecting the lower protection set and the upper protection set providing a hole through it in communication with the rising naval tube and the well; and an ejector device connected between the upper protection assembly and the lower protection assembly, the ejector device operable to physically separate the upper assembly and the connected rising naval tube from the lower protection assembly.
    [005] According to one or more aspects of the invention, a sequence of protection of submerged wells comprises the use of a protection set installed between a pile of explosion protectors from a submerged well and a rising naval tube, the protection set comprising a lower protection set connected to the explosion protection stack and an upper protection set connected to the rising naval tube forming a hole between the rising tube and the explosion protector stack; fixing a tube suspended in the hole in a position in the lower protection assembly; fixing the tube in a position in the upper protection assembly; shearing of the tube in the hole between the position in the lower protection set and the position in the upper protection set in which the tube was fixed; and physically separating the upper protection assembly and the rising naval tube from the lower protection assembly connected to the explosion protection stack.
    [006] The aforementioned outlined some of the devices and technical advantages of the invention in order that the following detailed description of the invention can be better understood. Additional devices and advantages of the invention that form the subject of the claims of the invention will be described below. BRIEF DESCRIPTION OF THE DRAWINGS
    [007] The exhibition is best understood from the detailed description below when dealing with the attached figures. It is emphasized that, according to industry standard practice, several devices are not designed to scale. In fact, the dimensions of different devices can be arbitrarily increased or reduced for clarity of the discussion.
    [008] Figure 1 is a schematic illustration of a submerged protection system according to one or more aspects of the invention used in a submerged well drilling system 12.
    [009] Figure 2 represents a submerged protection system according to one or more aspects of the invention, where the protection sequence was initiated and the riser and the upper protection package are physically and hydraulically disconnected from the lower protection package, the stack of BOPs, and the well.
    [010] Figure 3 is a schematic illustration of a submerged well protection assembly according to one or more aspects of the invention in an isolated form.
    [011] Figure 4A-4B is a flow chart of a submerged well protection sequence according to one or more modalities of the submerged well protection system.
    [012] Figures 5-17 are schematic diagrams of protection sequence steps according to one or more modalities of the submerged well protection system.
    [013] Figure 5A is a sectional view of a purge system according to one or more modalities of the well protection packaging shown along line I-I of Figure 5.
    [014] Figure 8A is a sectional view of a deflector device embodiment shown along line I-I of Figure 8.
    [015] Figure 8B is a side section view of an embodiment of the impact device of Figure 8A in an isolated form.
    [016] Figure 13A illustrates the riser and upper protective packaging disconnected and separated from the lower protective packaging and the wellhead in response to the progression of the submerged well protection sequence. DETAILED DESCRIPTION
    [017] It should be understood that the following presentation provides many different modalities, or examples, for the implementation of different devices of different modalities. Specific examples of components and arrangements are described below to simplify the exposure. These are, of course, only examples and are not intended to be limiting. In addition, the exhibition may repeat numerals and / or reference letters in the various examples. This repetition aims at simplicity and clarity and does not in itself impose a relationship between the various modalities and / or configurations discussed. In addition, the formation of a first device over or over a second device in the description that follows may include modalities in which the first and second devices are formed in direct contact, and may also include modalities in which additional devices can be formed by interposing the first and second devices, so that the first and second devices cannot be in direct contact.
    [018] As used here, the terms "up" and "down"; "Superior and inferior"; "top" and "bottom"; and other similar terms that indicate positions in relation to a given point or element are used to describe some elements more clearly. Generally, these terms refer to a reference point as the surface from which drilling operations are initiated, with the upper point and the total depth of the well being the lower point, where the well (for example, drilling well , hole) is vertical, horizontal or inclined in relation to the surface.
    [019] In this exhibition, "hydraulically coupled" or "hydraulically connected" and similar terms can be used to describe bodies that are connected in such a way that fluid pressure can be transmitted between and among the connected items. The term "in fluid communication" is used to describe bodies that are connected in such a way that fluid can flow between and between connected items. It is noted that hydraulic coupling can include some arrangements where fluid cannot flow between items, but fluid pressure can nevertheless be transmitted. Therefore, fluid communication is a subset of hydraulic coupling.
    [020] A submerged well protection system is exposed to provide a means for mitigating environmental and economic damage that may result from the loss of control of a well, as occurred in the Macondo well being drilled from Deepwarwe Horizon on 20 April 2010. According to one or more aspects of the invention, the submerged well protection system provides a mechanism for separating the riser tube from the explosion protector stack and the well in a manner designed to limit physical damage to the drilling wells and to improve the potential for successful reconnection to the well, for example, through the BOP stack, to regain control of the well.
    [021] Figure 1 is a schematic illustration of a submerged well protection system, generally represented by the numeral 10, being used in a submerged well drilling system 12. In the represented embodiment, the drilling system 12 includes a pile of BOPs 14 which is placed on a submerged well head 16 of a well 18 (i.e., a drilling well) that penetrates the bottom of the sea 20. The stack of BOPs 14 conventionally includes a rising tube (“LMRP”) package 22 and explosion protectors ("BOP") 24. The stack of BOPs represented 14 also includes submerged test valves ("SSTV") 26. As will be understood by those skilled in the art with the benefit of this exposure, the stack of BOPs 14 does not is limited to the devices represented.
    [022] The submerged well protection system 10 comprises protection packaging, or set, here called catastrophic protection packaging ("CSP") 28 that is placed over the BOP system 14 and is operationally connected to a riser 30 that extends from platform 31 (for example, vessel, platform, ship, etc.) to the stack of BOPs 14 and therefore well 18. CSP 28 comprises an upper CSP 32 and a lower CSP 34 which are adapted to separate from each other in response to the initiation of a protection sequence, thereby disconnecting the riser tube 30 from the stack of BOPs 14 and well 18, for example, as shown in Figure 2. The protection sequence is initiated in response to parameters that indicate the occurrence of a failure in well 18 with the potential to lead to an explosion in the well. According to one or more embodiments of the invention, the submerged well protection system 10 can automatically initiate the protection sequence in response to the correspondence of monitored parameters for selected protection triggers. According to one or more embodiments of the invention, CSP 28 may include an accumulator 29, see Figures 3 and 7, hydraulically connected to the wellhead 16 to operate the wellhead connector lock. In the embodiment shown in Figure 7, the wellhead accumulator 29 is represented as an isolated accumulator located near the bottom of the sea 20 and wellhead 16.
    [023] Wellhead 16 is a termination of the drilling well on the seabed and generally has the necessary components (for example, connectors, latches, etc.) to connect components such as BOPs 24, valves (for example, valves test trees, production trees, etc.) to the drilling well. The wellhead also incorporates the components necessary to suspend the casing, production piping, and underground flow control and production devices in the drilling well.
    [024] The stack of BOPs 14 generally includes a set of two or more BOPs 24 used to ensure pressure control of well 18. A typical stack can consist of one to six ram protectors and, optionally, one or two annular protectors . A typical stack configuration has ram protectors at the bottom and ring protectors at the top. The configuration of the stack protectors is optimized to provide maximum integrity, protection and pressure flexibility in the event of a well control incident. For example, a set of rams can be equipped to close over the drill pipe, blind rams to close over the open hole, and another set of shear rams to cut and suspend the drill pipe. It is also common to have an annular protector at the top of the stack to close over a wide range of tubular dimensions (eg, drill pipe) and the open hole. The stack of BOPs 14 also includes several spools, adapters, and piping ports to allow the circulation of fluids from the drilling well under pressure in the event of a well control incident.
    [025] The LMRP 22 and the stack of BOPs 24 are coupled together by a drilling well connector that is coupled to a corresponding mandrel on the top end of the stack of BOPs 24. The LMRP 22 typically provides the interface (ie , connection) of the BOPs 24 and the bottom end 30a of the riser 30 by means of a riser connector 36 (i.e., riser adapter). The riser connector 36 generally comprises a riser adapter for connecting the lower end 30a of the riser 30 (for example, screws, solder, hydraulic connector) and a flexible hinge that provides a range of angular movement for the riser 30 (for example, 10 degrees) in relation to the stack of BOPs 14, for example, to compensate for vessel displacement 31 and the effects of currents along the length of the riser 30. The riser connector 36 may further comprise one or more ports for connection of fluid (ie hydraulic) and electrical conductors, ie umbilical communication cables, which can extend along (outside or inside) the riser 30 from the drilling platform located on surface 5 to the submerged drilling 12. For example, it is common for a hydraulic obstruction pipe 44 and a hydraulic interruption pipe 46 to extend from the surface to the cone connection to the BOP stack 14.
    [026] The riser 30 is a tubular chain that extends from the drilling platform 31 down to the well 18. The riser is actually an extension of the drilling well that runs through the water column to the watercraft. drilling 31. The diameter of the drill pipe is large enough to allow the drill pipe, housing strings, logging tools and the like to pass through it. For example, in Figures 1 and 2, a pipe 38 (for example, drill pipe) is illustrated implemented from the drilling platform 31 into the riser pipe 30. Drilling mud and drilling cuts can be returned to surface 5 through of the riser 30. The umbilical communication cable (for example, hydraulic, electrical, optical, etc.) can be implemented outside or through the riser 30 to CSP 28 and stack of BOPs 14. A vehicle operated remotely (" ROV ") 124 is represented in Figure 2 and can be used for several tasks.
    [027] Reference is now made to Figure 3 which illustrates a submerged well protection package 28 according to one or more aspects of the invention in isolation. The CSP 28 shown in Figure 3 is further described with reference to Figures 1 and 2. In the embodiment shown, the CSP 28 comprises the upper CSP 32 and the lower CSP 34. The upper CSP 32 comprises a riser connector 42 which may include a riser flange connection 42a, and a riser adapter 42b that can provide connection of umbilical communication cables and extension of the umbilical communication cables to various devices of the CSP 28 and / or devices of the stack of BOPs 14. For example , an obstruction pipe 44 and an interruption pipe 46 are shown extending from the surface with the riser 30 and crossing the riser adapter 42b for connection to the obstruction and interruption pipes of the stack of BOPs 14. A CSP 28 comprises an obstruction punch 44a and an interruption pipe punch 46a to interconnect the upper portion of the obstruction pipe 44 and the internal pipe eruption 46 with the lower portion of the obstruction pipe 44 and the interruption pipe 46. As will be further described below with reference to the protection sequence 86, the perforators 44a, 46a also provide disconnection of the obstruction and interruption pipes during a protection; and during subsequent recovery and re-entry operations that reconnect the obstruction and interruption pipes by means of perforators 44a, 46a. In some embodiments, the riser connector 42 may also comprise a flexible hinge.
    [028] CSP 28 comprises a longitudinal inner hole 40, shown in Figure 3 by the dashed line through the lower CSP 34, for the passage tube 38. Ring 41 is formed between the outer diameter of tube 38 and the diameter of the hole 40.
    [029] The upper CSP 32 also includes wedges 48 (that is, safety wedges) adapted to close on the tube 38. The wedges 48 are activated in the modality represented by the hydraulic pressure from an accumulator 50. In the represented modality, the CSP 28 comprises several hydraulic accumulators 50 that can be interconnected in sheaths, such as the upper sheath of accumulators 52. As will be understood by those skilled in the art with the benefit of the present exhibition, accumulators 50 can be provided in different configurations. In the embodiment shown, accumulators 50 are charged hydraulically and do not require connection to a hydraulic source on the surface. It will also be recognized by those skilled in the art that hydraulic pressure can be provided from the surface. In this embodiment, the accumulators 50 located in the upper sheath of accumulators 52 are at least hydraulically connected to the wedges 48. In one or more embodiments of the invention, the pressure in the accumulators 50 is monitored and the accumulators 50 can be activated in sequence and as necessary to ensure that adequate hydraulic pressure is available and provided to drive CSP devices such as wedges 48.
    [030] The lower CSP 34 comprises a connector 54 to connect to the stack of BOPs 14, for example, via the riser connector 36, rams 56 (for example, blind rams), high energy blades 58, lower wedges 60 (for example, bidirectional wedges), and a purge system 64 (for example, valve collector). The bleed system 64 comprises one or more valves 66. In this embodiment, the bleed system 64 comprises bleed valves (for example, ball valves) 66a, blocking valves 66b, and one or more connecting chucks 68. The valves 66b can be used to control the flow of fluid through connection spindles 68. For example, a recovery riser 126 is depicted connected to one of spindles 68 for draining effluent from the well and / or circulating a stop fluid (eg drilling mud) into the well, as will be further described below. Purge system 64 is further described below with reference to Figures 5 and 5A.
    [031] In the embodiment shown, the lower CSP 34 further comprises a deflector device 70 (for example, impact device, obturator ram) positioned above the purge system 64 and below the lower wedges 60, blades 58, and blind rams 56. The lower CSP 34 includes several hydraulic accumulators 50 that are positioned and connected in one or more lower hydraulic sheaths 62 for maneuvering various CSP 28 devices. As will be further described below, the CSP 28, in particular the lower CSP 34, may include a source of methanol, or another chemical 76, operatively connected for injection into the lower CSP 34, for example, to prevent the formation of hydrates.
    [032] The upper CSP 32 and the lower CSP 34 are connected to each other in a detachable manner by a connector 72. The connector of CSP 72 is represented in the embodiments illustrated as a crimp connector, comprising a first connector part 72a and a second mandrel connector part 72b which are illustrated, for example, in Figure 13A. An ejector device 74 (for example, ejector heads) is operationally connected between the upper CSP 32 and the lower CSP 34 to separate the upper CSP 32 and riser 30 from the lower CSP 34 and stack of BOPs 14 after the connector 72 has been actuated to the locked position. CSP 28 also includes several sensors 84 that can detect various parameters, such as and without limitation, temperature, pressure, tension (traction, compression, torque), vibration, and fluid flow rate. Sensors 84 further include, without limitation, erosion sensors, position sensors, and accelerometers and the like. Sensors 84 can be in communication with one or more control and monitoring systems, for example, as further discussed below, forming a package of limit state sensors.
    [033] According to one or more embodiments of the invention, CSP 28 comprises a control system 78 that can be in a submerged location, for example, in CSP 28 or in a remote location such as on the surface. The control system 78 can comprise one or more controllers that are located in different locations. For example, in at least one embodiment, control system 78 comprises an upper controller 80 (for example, upper command and control data bus) and a lower controller 82 (for example, upper command and control bus). The control system 78 can be connected by means of conductors (for example, wire, cable, optical fibers, hydraulic pipes) and / or wireless (for example, acoustic transmission) to various submerged devices and surface control systems ( for example, drilling platform 31).
    [034] With reference to the modalities represented in Figures 3 to 17, the control system 78 includes the upper controller 80 and the lower controller 82. Each of the upper and lower controllers 80, 82 can comprise a collection of computational circuits in real time , sets of field programmable ports (FPGA), I / O modules, power circuits, energy storage circuits, software, and communications circuits. One or both of the upper and lower controllers 80, 82 may comprise control valves.
    [035] According to at least one modality, one of the controllers, for example, the lower controller 82, functions as the main controller and provides command and control sequencing for several subsystems of the protective packaging 28 and / or sends commands coming from a regulatory authority, for example, located on the surface. The main controller, for example, the lower controller 82, contains communication functions and sanitary and status parameters (for example, riser pipe pressure, riser pipe pressure, riser pipe temperature, wellhead pressure, head temperature well, etc.). One or more of the controllers may be black-box capable (for example, continuous recording storage device that does not require power for data recovery).
    [036] The upper controller 80 is described here as operationally connected to several sensors 84 positioned throughout the CSP 28 and may include sensors connected to other parts of the drilling system, including along the riser 30, at the wellhead 16 and in well 18. The upper controller 80, using data sent by sensors 84, continuously monitors the limit state conditions of the drilling system 12. According to one or more modalities, the upper controller 80 can be programmed and reprogrammed to adapt to the personality of the well system based on the data detected during maneuvers. If a defined limit state is exceeded, an activation signal (for example, alarm) can be transmitted to the surface and / or lower controller 82. A protection sequence can be initiated automatically by the control system 78 and / or manually in response the activation signal.
    [037] With reference to Figures 4A and 4B, a protection sequence 86 is exposed according to one or more modalities of the submerged well protection system 10. In sequence step 88, the protection sequence is initiated in response to monitoring from the limit state sensor package 84 by the upper controller 80. In sequence step 90, pressure is discharged from CSP 28 by opening a valve 66a in the bleed system 64, see, for example, Figures 1, 3, 5 and 5A. In the sequence step 92, the obstruction and interruption pipes are closed to prevent fuels from flowing upwards through the pipes, see, for example, Figures 1, 3 and 6. In the sequence step 94, the wellhead connector lock 16 is pressurized to prevent accidental ejection of the stack of BOPs 14 from the wellhead 16, see, for example, Figures 3 and 7. In sequence step 96, fluid flowing upward from the well is diverted, for example, partially deflected, to the purging holes opened to prevent erosion of CSP elements such as wedges 48, 60, see, for example, Figures 1, 3, 8, 8A and 8B. For example, the fluid flow can be diverted by maneuvering a deflection device 70 to a closed position. In the sequence step 98, the tube 38 is fixed in the lower CSP 34 by closing the lower wedges 60 (for example, bidirectional wedges), see, for example, Figures 1, 3 and 9. In the sequence step 100, the tube 38 is fixed to the upper CSP 32 by closing the upper wedges 48 (for example, safety wedges), see, for example, Figures 1, 3 and 10. In sequence step 102, the tube 38 is sheared in the lower CSP 34 by activation of blades 58, see, for example, Figures 1, 3 and 11. In the sequence step 104, the upper CSP 32 and the lower CSP 34 are disconnected from each other by maneuvering the CSP connector 72 to a disconnected position, see, for example, Figures 1, 3, 12 and 13A. In the sequence step 106, the riser 30 and the upper CSP 32 are separated (for example, ejected) from the lower CSP 34 and stack of BOPs 14 by activating the ejector device 74 (ie, ejector heads), see, for example , Figures 1-3, 13 and 13A. In the sequence step 108 (see, for example, Figures 1-3 and 14) blind rams 56 are closed to cut the fluid flow from the BOP stack 14 through hole 40 (see Figure 3) to the environment. In the sequence step 110, the formation of hydrates in the lower CSP 34 is treated by injection of methanol, see, for example, Figures 1-3 and 15. In the sequence step 112, the orifices are closed. purge 66a opened in purge system 64 in sequence step 90, see, for example, Figures 1-3 and 16. In sequence step 114, a formation stability test is performed, see, for example, Figures 1- 3 and 17.
    [038] Figure 5 is a schematic diagram of the sequence step 90, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. In response to the initiation of the sequence of protection 86, one or more bleed valves 66a of the bleed system 64 are opened. Valves 66a are opened to reduce the flow of fluid through the ring 41 between the tube 38 and the walls of the CSP 28 that form the hole 40 through the CSP 28 (see Figure 3, the dashed lines in the lower CSP 34) and decrease the back pressure of the lower wedges 60. The open and closed positions of the bleed valves 66a can be checked by a control signal coming from each valve position sensor 84. An accumulator 50 located in the hydraulic power to the valve actuators 116 of the controller 82. The lower controller 82 continuously monitors the pressure of the accumulator sheath 62 and activates additional accumulators 50 as needed to maintain the working pressure. With reference to Figures 5-17, the active devices (for example, accumulators, valves, wedges, blades) of the represented sequence step are emphasized by hatching.
    [039] Figure 5A is a sectional view of a modification of purge system 64 shown along line II of Figure 5. Figure 5A depicts two purge valves 66a on each side of purge system 64, which are represented in the closed position. Valves 66b are positioned to control the flow through connection chucks 68. In the embodiment shown, sensor 84 located next to connection chuck 84 is an accelerometer.
    [040] Figure 6 is a schematic diagram of the sequence step 92, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. In the sequence step 92, the valves 118 positioned in each of the obstruction line 44 and the interruption line 46 are actuated from the open to the closed position to prevent fuels from flowing upwards through the obstruction line 44 and the interruption line 46.
    [041] Figure 7 is a schematic diagram of the sequence step 94, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. Controller 82 initiates pressurization of the wellhead connector connector latch 120 to prevent accidental ejection of the BOP stack 14 from wellhead 16 due to the high back pressure found in subsequent sequence steps, for example, when deflector 70 is closed, wedges 48, 60 are closed; and due to the loss of hydraulic pressure to the wellhead connector lock 120 when the riser 30 is disconnected from the stack of BOPs 14 disconnect any hydraulic sources extending along the riser 30 of the CSP 28.
    [042] Figure 8 is a schematic diagram of the sequence step 96, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1, 3, 8A and 8B. In sequence step 96, the controller 82 activates the deflector device 70, described in the modalities of Figures 8, 8A and 8B as shutter ram 70, to a closed position (see Figure 8A) in response to the application of hydraulic pressure in the mode of Figure 8 from a hydraulic accumulator 50 of the lower accumulator sheath 62. In the closed position, the deflector device 70 diverts flow fluid through the ring 41 of the CSP 28 to the bleed system 64 and opens the bleed valves 66a. Closed shutter ram 70, shown in Figure 8A, protects CSP 28 from the high flow rates and entrained solids that are encountered, thereby limiting the erosion of CSP 28 devices, such as upper wedges 48 and lower wedges 60 The shutter ram 70 can be provided in several modes and configurations. With reference to Figure 8A, the tube 38 is shown substantially centered inside the hole 40 of the plug ram 70, which is coaxial with the hole 40 of the CSP 28 by the ram 70A, 70B and 70C. According to at least one embodiment, the closing of the ram 70A, 70B and 70C does not seal the ring 41. In the embodiment shown in Figure 8B, each of the ram 70A, 70B and 70C comprises stacked and separated plates 71 that are interspersed with the plates 71 of the adjacent ram.
    [043] Figure 9 is a schematic diagram of the sequence step 98, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. In the sequence step 98, the controller 82 drives the lower wedges 60 (i.e. bidirectional wedges) securing the tube 38 within the lower CSP 34 in preparation for sequence step 102. In some embodiments, the lower wedges 60 may comprise deflector shield to deflect fluid flow towards the purge system 64 instead of, or in addition to, the shutter ram device 70 described and exposed with reference to sequence step 96 and Figures 8, 8A and 8B.
    [044] Figure 10 is a schematic diagram of the sequence step 100, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. In the sequence step 100, the upper wedges 48 are activated to engage the tube 38 within the upper CSP 32. In this mode, the sequence step 100 is triggered by the upper controller 80. As with other sequence steps, the controller monitors the pressure status of the accumulators 50 and , if a low pressure is detected, a subsequent accumulator in a sheath is activated to drive the sequence step device (i.e., wedges 48 in sequence step 100).
    [045] Figure 11 is a schematic diagram of the sequence step 102, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1 and 3. After the tube 38 is engaged and fixed respectively to the upper CSP 32 (that is, wedges 48) and lower CSP 34 (that is, wedges 60), the lower controller 82 drives the blades 58, thus shearing the tube 38 between the upper wedges 48 and the lower wedges 60.
    [046] Figure 12 is a schematic diagram of the sequence step 104, according to one or more modalities of the submerged well protection system 10 which is described with further reference to Figures 1, 2, 3 and 13A. In sequence step 104, the CSP connector 72 is triggered to the open, or disconnected position, which allows separation of the upper CSP 32 from the lower CSP 34 in sequence step 106. In this embodiment, the CSP connector 72 is activated by means of the upper controller 80 and hydraulic accumulators 50 located in the upper sheath of accumulators 52. In the embodiment shown, the CSP connector 72 is a crimp comprising a first connector part 72a and a second connector part 72b, represented for example, in Figure 13A. The second connector part 72b is positioned with the lower CSP 34 and comprises a mandrel, individually identified by the numeral 72c (see, Figures 13A, 14-17). Chuck 72c provides a mechanism for reconnecting, for example, with a riser tube, for re-entry into well 18.
    [047] Figure 13 is a schematic diagram of sequence step 106, according to one or more embodiments of the submerged well protection system 10 which is described with further reference to Figures 1-3 and 13A. In sequence step 106, ejector devices 74 (i.e., ejector heads) are actuated to physically separate the upper CSP 32 and the riser 30 from the lower CSP 34, as shown in Figures 2 and 13A. For example, ejector devices 74 may include piston rods 74a that extend to push the upper CSP 32 away from the lower CSP 34 in the embodiment shown. Figures 2, 13A and 14-17 illustrate the piston rod 74a in an extended position. In the modality of Figure 13, the activation of the ejector devices 74 is provided by the upper controller 80 and accumulator (s) 50 located in the upper sheath of accumulators 52.
    [048] Typically, the riser 30 will be in tension, which will help to pull the upper CSP 32 vertically disconnected from the lower CSP 34. In addition, the water and deflection currents in the riser 30 (for example, displacement of the platform 31) will help to move the riser 30 and separate the upper CSP 32 laterally away from the lower CSP 34 and the well. The obstruction pipe 44 and the interruption pipe 46 are disconnected, respectively, in the obstruction punch 44a and interruption punch 46a (Figure 3). Drills 44a and 46a provide a means for 24/32 reconnection to surface sources during recovery maneuvers.
    [049] In the embodiments shown, the ejector device 74 is attached to the lower CSP 34 and the piston rods 74a push a part of the upper CSP 32, for example, a part of the frame 122 of the upper CSP 32 shown generally in Figure 13. It is understood by those skilled in the art with the benefit of this exposure that the ejector device 74 can be provided in different configurations without departing from the scope of the invention. For example, the ejector device 74 can be inverted so that it is fixed with the upper CSP 32 where the piston rod 74a acts against the lower CSP 34.
    [050] Figure 14 is a schematic diagram of the sequence step 108, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1, 2 and 3. In sequence step 108 , blind rams 56 are driven to the closed position sealing hole 40 (see Figures 3 and 8A, 8B) to block any fluid that can flow upwards from well 18 through the stack of BOPs 14. In the represented mode, the drive of the blind rams 56 is provided by the lower controller 82 and accumulator (s) 50 located in the lower sheath (s) of accumulators 62.
    [051] Figure 15 is a schematic diagram of the sequence step 110, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1, 2 and 3. In sequence step 110 , methanol 76 can be injected into the lower CSP 34 to prevent hydrate formation in the CSP 28, especially in the bleed holes (for example, bleed valves 66a) of the bleed system 64. In the embodiment shown, the methanol injection 76 it is provided by the lower controller 82 and can be powered by the accumulator (s) 50 located in the lower accumulator sheath (s) 62.
    [052] Figure 16 is a schematic diagram of the sequence step 112, according to one or more modalities of the submerged well protection system 10 which is described with additional reference to Figures 1, 2 and 3. In sequence step 112 , the lower controller 82 activates the hydraulic energy (for example, accumulator 50) to drive the open bleed valves 66a from the open to the closed position.
    [053] Figure 17 is a schematic diagram of the sequence step 114, according to one or more modalities of the submerged well protection system 10 which is described with further reference to Figures 1-3. Subsequent to the closing of the bleed valves 66a in sequence step 112, the lower controller 82 can initiate and perform a formation stability test, for example, by monitoring the wellhead temperature and pressure using one or more sensors 84 .
    [054] If stable formation conditions are indicated, protection system 10 can be placed in a waiting condition until recovery maneuvers can be started and ended. If unstable formation conditions are indicated, bleed valves 66a can be opened to relieve pressure in an effort to prevent an underground explosion from well 18, which would result in loss of the well and would require more difficult and time-consuming processes to close the well. 18. With effluent discharging into the environment, a recovery riser 126 that extends, for example, from a vessel on surface 5, can be connected to connection chuck 68 of the purge system 64 as shown in Figure 3. An ROV 124 (Figure 2) can be used to connect the flexible riser 126. A valve, such as valve 68b, can be maneuvered to the open position allowing flow of effluent through the chuck 68 of the purge system 64 to inside the riser 126 and to the surface; and the open vent valves 66a are maneuvered to the closed position, thereby providing a means to limit environmental damage until control of well 18 is regained.
    [055] According to one embodiment, a recovery method for well 18 comprises closing in well 18 by means of the lower CSP 34 and / or effluent discharge from well 18 through the purge system 64 and a riser pipe recovery 126 to the surface. A riser 30 and the hydraulic blocking pipe 44 and / or the hydraulic stopping pipe 46 extend from the surface to the lower CSP 34. The blocking and stopping pipes 44, 46 can be connected to the stack of BOPs 14 and well 18 through the obstruction perforator 44a and interruption perforator 46a which are located on the lower CSP 34 which is still connected to the well 18. The riser 30 in some circumstances can be connected to the connector chuck 72b of the CSP connector 72 to re-establish hydraulic communication with well 18 via the BOP stack 14. Depending on the state of the BOP stack 14 and stability of the formation, drilling mud can be circulated downward by a riser 30, obstruction pipe 44, interruption pipe 46, and / or flexible riser 126 to interrupt well 18.
    [056] According to one or more aspects of the invention, a submerged well protection package for installation on a pile of explosion protectors in a submerged well comprises a protection set connector that interconnects a lower set and an upper set of protection, the protection set connector operable to a disconnected position, where the lower protection set is adapted to be connected to a pile of explosion protectors in a submerged well and the upper protection set is adapted to be connected to a pipe ascending naval; the lower assembly comprising lower wedges for engaging a tube suspended in a hole formed through the lower and upper protective assemblies; the upper protective package comprising upper operable wedges for engaging the tube; and a blade positioned between the upper and lower wedges, the blade operable to shear the tube.
    [057] According to one or more aspects of the invention, a submerged well protection package is provided for installation on a pile of explosion protectors in a submerged well that comprises a protection set connector that interconnects a lower set and a upper protection assembly, the protective assembly connector operable to a disconnected position, where the lower protection assembly is adapted to be connected to a pile of explosion protectors in a submerged well and the upper protection assembly is adapted to be connected to an ascending naval tube; the lower assembly comprising lower wedges for engaging a tube suspended in a hole formed through the lower and upper protective assemblies; the upper protective package comprising upper operable wedges for engaging the tube; a blade positioned between the upper and lower wedges, the blade operable to shear the tube; and an ejector device connected between the lower protective assembly and the upper protective assembly, the ejector device operable to physically separate the upper protective assembly from the lower protective assembly.
    [058] The package may include a bleed hole carried by the lower protection assembly, the bleed hole operable between an open position and a closed position. In at least one embodiment, the package also includes a bleed hole carried by the lower protection assembly and positioned below the lower wedge when connected to the well, where the bleed hole is operable between an open position and a closed position.
    [059] According to one or more embodiments of the invention, the ejector device includes an extensible piston rod. The piston rod can be extensible in response to the application of hydraulic pressure.
    [060] According to one or more embodiments of the invention, the protective packaging comprises a hydraulic accumulator positioned with the protection set and in hydraulic communication with the lower wedges. In some embodiments, several hydraulic accumulators are arranged in an upper accumulator sheath, where the upper accumulator sheath is in hydraulic communication with the upper wedges. According to at least one modality, the blade is in hydraulic communication with at least one of the lower sheath of hydraulic accumulators and an upper sheath of hydraulic accumulators. Similarly, the ejector device is in hydraulic communication with at least one of the lower sheath of hydraulic accumulators and an upper sheath of hydraulic accumulators in some embodiments.
    [061] According to one or more modalities, a bleed hole is carried by the lower protection assembly and positioned below the lower wedge when connected to the well, where the bleed hole is operable between an open position and a closed position; and a deflector device is positioned between the lower wedges and the bleed port, where the deflector device is operable to a closed position to deflect the flow of fluid towards the bleed hole. In some embodiments, the deflecting device does not seal the tube suspended in the lower protection assembly when in the closed position.
    [062] A submerged well protection system according to one or more aspects of the invention comprises a protection set comprising a lower protection set connected to a stack of explosion protectors connected to a submerged well and an upper protection set connected to an ascending naval tube; a protection set connector that interconnects the lower protection set and the upper protection set providing a hole through it in communication with the rising naval tube and the well; ; and an ejector device connected between the lower protective assembly and the upper protective assembly, the ejector device operable to physically separate the upper protective assembly from the lower protective assembly.
    [063] The protection set may also comprise, for example, lower wedges operable to engage a suspended tube in the hole of the lower protection set; operable upper wedges to engage the suspended tube in the hole of the upper protection assembly; a blade located between the upper wedges and the lower wedges operable for shearing the tube; and a bleed hole in communication with the hole, the bleed hole operable between an open position and a closed position. In some embodiments, the protection system further comprises a deflector device located in the lower protection assembly between the lower wedges and the bleed hole, the deflector device operable to a closed position to divert the flow of fluid towards the bleed hole.
    [064] According to one or more aspects of the invention, a submerged well protection sequence comprises the use of a protection set installed between a pile of explosion protectors from a submerged well and a rising naval tube, the protection set comprising a lower protection set connected to the explosion protection stack and an upper protection set connected to the rising naval tube forming a hole between the rising tube and the explosion protector stack; fixing a tube suspended in the hole in a position in the lower protection assembly; fixing the tube in a position in the upper protection assembly; shearing of the tube in the hole between the position in the lower protection set and the position in the upper protection set in which the tube was fixed; and physically separating the upper protection set and the rising naval tube from the lower protection set connected to the explosion protection stack.
    [065] The aforementioned describes characteristics of several modalities so that those versed in the technique can better understand the aspects of the exhibition. Those skilled in the art should understand that they can easily use the exhibition as a basis for designing or modifying other processes and structures to carry out the same purposes and / or obtain the same advantages from the modalities introduced here. Those skilled in the art should also understand that such equivalent constructions do not differ from the scope and scope of the exhibition, and that they can make several changes, substitutions and changes to those without diverging from the scope and scope of the exhibition. The scope of the invention should be determined only by the language of the claims that follow. The term "comprising" within the claims is intended to mean "including at least" so that the listing of elements listed in a claim is an open group. The terms "one", "one" and other singular terms are intended to include their plural forms unless specifically excluded.
    权利要求:
    Claims (20)
    [0001]
    1. Submerged well protection packaging, characterized by the fact that it comprises: a set connector that interconnects a lower set and an upper set, where the lower set must be connected to the submerged well; the lower assembly comprising lower wedges for engaging and holding a tube suspended in a hole formed through the lower assembly and the upper assembly; the upper assembly comprising upper operable wedges for engaging and holding the tube; and a blade positioned between the upper wedges and the lower wedges, the blade operable for shearing the tube.
    [0002]
    2.Packaging according to claim 1, characterized by the fact that it also comprises a bleed hole carried by the lower assembly, the bleed hole operable between an open position and a closed position.
    [0003]
    3.Packaging according to claim 1, characterized by the fact that it comprises a bleed hole loaded by the lower assembly and positioned below the lower wedges when connected to the submerged well, where the bleed hole is operable between an open position and a closed position.
    [0004]
    4.Packaging according to claim 1, characterized by the fact that it comprises an ejector device connected between the lower assembly and the upper assembly, the ejector device operable to separate the upper assembly from the lower assembly.
    [0005]
    5.Packaging, according to claim 1, characterized by the fact that the lower set comprises a blind ram located between the lower wedges and the operable set connector to seal the hole.
    [0006]
    6.Packaging, according to claim 1, characterized by the fact that it comprises an ejector device connected between the lower assembly and the upper assembly, operable to separate the upper assembly and the lower assembly; and the lower assembly comprising a blind ram located between the lower wedges and the operable assembly connector to seal the hole.
    [0007]
    7.Packaging according to claim 6, characterized by the fact that it comprises a bleed hole loaded by the lower assembly and positioned below the lower wedges when connected to the submerged well, where the bleed hole is operable between an open position and a closed position.
    [0008]
    8.Packaging according to claim 1, characterized by the fact that it comprises: a bleed hole carried by the lower assembly and positioned below the lower wedges when connected to the submerged well, where the bleed hole is operable between an open position and a closed position; and a deflector device positioned between the lower wedges and the bleed hole, the deflector device operable in a closed position to be in contact with the tube in the hole.
    [0009]
    Packaging according to claim 8, characterized by the fact that the deflecting device does not seal the tube.
    [0010]
    10.Packaging according to claim 8, characterized by the fact that it comprises an ejector device connected between the lower assembly and the upper assembly, and operable to separate the upper assembly and the lower assembly; and the lower assembly comprising a blind ram located between the blades and the operable assembly connector to seal the hole.
    [0011]
    11. Submerged well system, characterized by the fact that it comprises: a protective packaging comprising a lower set connected to a submerged well and an upper set connected to an ascending naval tube; an assembly connector in a locked position interconnecting the lower assembly and the upper assembly and providing a hole through the protective packaging in communication with the riser and submerged well, the assembly connector operable in an unlocked position to thereby , disconnect the upper assembly from the lower assembly; the lower assembly comprising lower wedges to engage and hold a tube suspended in the hole; the upper sets comprising operable upper wedges to engage and hold the tube; and a blade positioned between the upper wedges and the lower wedges, operable for shearing the tube.
    [0012]
    12. The system according to claim 11, characterized by the fact that it comprises an ejector device connected between the lower assembly and the upper assembly, the ejector device operable to physically separate the upper assembly from the lower assembly.
    [0013]
    13. The system according to claim 11, characterized by the fact that the protective packaging comprises a bleed hole in communication with the hole and located between the submerged well and the lower wedges, the bleed hole operable between an open position and a closed position.
    [0014]
    14. The system according to claim 11, characterized by the fact that the protective packaging comprises: a bleed hole in communication with the hole and located between the submerged well and the lower wedges, the bleed hole operable between a position open and a closed position; and a deflector device located in the lower assembly between the lower wedges and the vent hole, the deflector device operable in a closed position to be in contact with the tube in the hole.
    [0015]
    15. Method of protection of submerged wells, characterized by the fact that it comprises: using a protective package installed between a submerged well and a rising naval tube, the protective package comprising a lower set connected to the submerged well and an upper set connected to the ascending naval tube, forming a hole between the ascending tube and the submerged well, in which the lower set comprises lower wedges and the upper set comprises upper wedges; fix a pipe suspended in the hole with the lower wedges in a position in the lower assembly; fix the tube with the upper wedges in a position in the upper assembly; shear the pipe in the hole between the position in the lower assembly and the position in the upper assembly in which the pipe was fixed; and after shearing the tube, disconnect the upper assembly from the lower assembly.
    [0016]
    16. Method according to claim 15, characterized by the fact that disconnecting comprises the physical separation of the upper set from the lower set.
    [0017]
    17. Method, according to claim 15, characterized by the fact that disconnecting comprises the actuation of an ejector device connected between the upper set and the lower set, thereby physically separating the upper set from the lower set.
    [0018]
    18. Method according to claim 15, characterized by the fact that it comprises, after shearing the tube, sealing the hole in the lower assembly.
    [0019]
    19. Method according to claim 15, characterized by the fact that it comprises, before fixing the pipe, the pressure discharge from the hole through a bleed hole located in the lower assembly below the position in which the pipe must be fixed to the lower assembly.
    [0020]
    20. Method according to claim 15, characterized by the fact that it also comprises, before fixing the tube: the pressure discharge from the hole through a bleed hole located in the lower assembly below the position in which the tube it must be fixed in the lower set; and the deviation of fluid flow from the hole to the vent hole before fixing the tube.
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-09-17| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-03-24| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-11-17| B09W| Decision of grant: rectification|Free format text: RETIFICACAO NO QUADRO I DO PARECER |
    2021-03-16| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 29/08/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US37785110P| true| 2010-08-27|2010-08-27|
    US61/377,851|2010-08-27|
    PCT/US2011/049610|WO2012027755A1|2010-08-27|2011-08-29|Subsea well safing system|
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