SYSTEMS AND METHOD AND APPLIANCES FOR USE WITH AND OPERATION OF A PETROLEUM EXPLORATION DEVICE

专利摘要:
APPLIANCE AND CONNECTION METHOD An acoustic control system wirelessly operates a subsea connection assembly or other subsea device, such as an active seal. The acoustic control system can control a first subsea accumulator to release the hydraulic fluid it stores to operate the connection set or other subsea device such as an active seal. An RCD or other oil exploration device can be disconnected or connected using the connection set. The acoustic control system may have a surface control unit, an underwater control unit and two or more acoustic signal devices. A valve can allow switching from an umbilical line system to an acoustic control system accumulator.
公开号:BR112013009489B1
申请号:R112013009489-3
申请日:2011-10-17
公开日:2020-06-23
发明作者:Stephanus Wilhelmus Maria Nas；Waybourn J Anderson；Waybourn J Anderson Jr；Kevin Leon Gray；Thomas F Bailey；Thomas Fbailey
申请人:Weatherford Technology Holdings, Llc；
IPC主号:

专利说明:

The order claims priority for US Provisional Order Serial No. 61 / 394,155 and US Order Serial No. 13 / 233,846, which is partly a continuation of US Order Serial No. 122 / 643,093 filed on December 21, 2009 , which claims the benefit of US Provisional Order no. 61 / 205,209 filed on January 15, 2009. All patents, orders and other documents referred to in this report are incorporated in full into this document as a reference for all purposes to the extent permitted under the laws, relevant rules and regulations.
Modalities of the present invention refer in general to subsea drilling and especially to a system and method for connecting and / or disconnecting a rotary control device (RCD) or other oil exploration device.
Marine risers that extend from a wellhead fixed to the bottom of an ocean have been used to circulate the drilling fluid back to a structure or platform. An example of an underwater riser and some associated drilling components is proposed in U.S. Patent Nos. 4,626,135 and 7,258,171. RCDs have been proposed to be positioned with marine risers. U.S. Patent No. 6,913,092 proposes a seal housing with an RCD positioned above sea level in an upper section of an underwater riser to facilitate a mechanically controlled pressurized system. U.S. Patent No. 7,237,623 proposes a method for drilling from a floating structure using an RCD positioned in an underwater riser. U.S. Patent Nos. 6,470,975, 7,159,669 and 7,258,171 propose the placement of a set of RCDs in a housing arranged in a submarine riser. In the '171 patent, the system for drilling at the bottom of an ocean uses an RCD with a support assembly and an immobilization element to removably position the support assembly in an underwater housing. In addition, an RCD to be positioned on the seabed without an underwater riser has also been proposed in U.S. Patent No. 6,138,774.
More recently, the advantages of using an unbalanced drilling have been disclosed, especially in mature geological environments in deep waters. RCDs such as those described in U.S. Patent No. 5,662,181 provided a reliable seal between a rotating pipeline and the riser while drilling operations were being conducted. U.S. Patent No. 6,138,774 proposes the use of an RCD for super-balanced drilling of a well hole through underwater geological formations. U.S. Patent No. 6,263,982 proposes an unbalanced drilling concept of using an RCD to seal an underwater riser while drilling into an ocean floor from a floating structure. In addition, U.S. Provisional Order No. 60 / 122,350, filed March 2, 1999, entitled "Concepts for the Application of Rotating Control Head Technology to Deepwater Drilling Operations" proposes the use of an RCD for deepwater drilling. U.S. Patent No. 4,813,495 proposes a submarine RCD as an alternative to the conventional drilling system and method, when used in conjunction with an underwater pump that returns the drilling fluid to a drilling vessel.
Conventional RCD sets have been sealed with an underwater housing using active sealing mechanisms in the underwater housing. U.S. Publication No. 2010/0175882 proposes a mechanically extrusable seal or a hydraulically expanded seal to seal the ROD with the riser. In addition, conventional RCD sets, such as those proposed by U.S. Patent No. 6,230,824, used electrical connection mechanisms in the underwater housing for RCD positioning. U.S. patent 7,487,837 proposes a connection set for use with a riser for positioning an RCD. U.S. Patent No. 7,836,946 B2 proposes a connection system for connecting an RCD to an active housing and seals. U.S. Patent No. 7,926,593 proposes a housing for a docking station positioned above the water surface for connection to an RCD. U.S. publication No. 2009/0139724 proposes a connection position indicator system for remotely determining whether a connection set is connected or not.
U.S. Patent No. 6,129,152 proposes a flexible rotating bladder and seal assembly that is hydraulically connectable with its blowout preventive rotating element housing. U.S. Patent No. 6,457,529 proposes a circumferential ring that forces the pins outward to releasably connect an RCD with a distributor. U.S. Patent No. 7,040,394 proposes inflatable bladders / seals. U.S. Patent No. 7,080,685 proposes a rotating packer that can be removed via connection regardless of the supports and other non-rotating portions of the RCD. The '685 patent also proposes the use of an indicator pin driven by a plunger to indicate the position of the plunger.
The connection sets for RCDs were proposed to be operated on the seabed with an electro-hydraulic umbilical line starting from the surface. A remotely operated vehicle (ROV) and a human diver have also been proposed to operate the connection sets. However, an umbilical line can be damaged. It is also possible that for marine depths and / or certain conditions they may be unsafe and / or impractical for a diver or an ROV. In such situations, the submarine riser may have to be removed to extract the RCD.
U.S. Patent No. 3,405,387 proposes an acoustic control device for controlling the operation of subsea valve equipment from the surface. U.S. Patent No. 4,065,747 proposes an apparatus for transmitting command or control signals to subsea equipment. U.S. Patent No. 7,123,162 proposes an underwater communication system to communicate with a device on the seabed. U.S. publication No. 2007/0173957 proposes a modular cable unit positioned on the seabed for attaching devices such as sensors and motors.
U.S. Patent Nos. 3,405,387, 4,065,747, 4,626,135, 4,813,495, 5,662,181, 6,129,152, 6,138,774, 6,230,824, 6,263,982, 6,457,529, 6,470,975, 6,913,092, 7,040. 394, 7,080,685, 7,123,162, 7,159,669, 7,237,623, 7,258,171, 7,487,837, 7,836,946 B2, and 7,926,593 and US Publications Nos. 2007/0173957, 2009/0139724 and 2010/0175882; and US Provisional Order No. 60 / 122,350, filed on March 2, 1999, entitled "Concepts for the Application of Rotating Control Head Technology to Deepwater Drilling Operations", are all incorporated into this document as a reference for all purposes, to the extent permitted under relevant laws, rules and regulations.
The inventors noted that it would be desirable to have a system and method for disconnecting an RCD or other oil exploration device from a subsea connection set when the umbilical line that is primarily responsible for the operation of the connection set is damaged or when the use of the umbilical line is impractical or not desirable, and the use of a diver or an ROV can be dangerous or impractical.
According to the modalities of the present invention, an acoustic control system can remotely operate a subsea connection set. In one embodiment, the acoustic control system can control a first underwater accumulator that stores hydraulic fluid. The hydraulic fluid may be pressurized. The first accumulator can be loaded and purged remotely and / or manually. In response to an acoustic signal, the first accumulator can release its fluid to operate the subsea connection set. The released fluid can trigger a plunger from the connection set to disconnect an RCD or other oil exploration device. The connection set can be arranged with an underwater riser and / or an underwater wellhead if there is no underwater riser. If there is an undersea riser, the connection assembly may be arranged below the tension lines or tension ring that supports the top of the riser from the drilling structure or platform.
The acoustic control system may have a surface control unit, an underwater control unit, and two or more acoustic signal devices. One of the acoustic signal devices may be able to transmit an acoustic signal. In one embodiment, the acoustic signal devices may be able to receive the acoustic signal. In one embodiment, the acoustic signal devices can be transceivers connected with transducers, each of which is capable of transmitting and receiving acoustic signals between the two to provide two-way communication between the surface control unit and the subsea control unit . The subsea control unit can control the first accumulator.
A second accumulator or compensator can be used to capture hydraulic fluid that is released from the connection system to prevent it from escaping into the environment. The acoustic control system can be used as a secondary or safety system in the event of damage to the primary electrohydraulic umbilical line, or it can be used as the primary system for the operation of the connection set. In one embodiment, one or more valves or a set of valves can be arranged with the accumulators and the umbilical line to switch to the secondary acoustic control system depending on the need.
In other modalities, the acoustic control system can be used to connect and / or disconnect the RCD or other oil exploration device with the submarine housing or submarine riser, including the primary and / or secondary movable pistons within the connection set. In another modality, the system can be used to operate active seals to retain and / or release an RCD or other oil exploration device arranged with the underwater housing or the underwater riser.
Some embodiments of the invention will now be described by way of example only and with reference to the attached drawings in which:
Figure 1 is a cross-sectional elevation view of an RCD that has two passive seals and is connected with a drum or riser housing having two connection elements shown in the connected position and an active packer seal shown in the unsealed position.
Figure IA is a sectional view taken along the step line 1A-1A of Figure 1 showing the second retaining element in the form of a multiplicity of struts in the connected position, a multiplicity of vertical grooves on the outer surface of the RCD and a multiplicity of fluid passages between the struts and the RCD.
Figure 2 is a cross-sectional elevation view of an RCD with three passive seals connected with a drum or riser housing having two connection elements shown in the connected position, an active seal shown in the unsealed position and a channel or line. deviation that has a valve inside.
Figure 3A is a partial elevation cross-sectional view of an RCD having a seal assembly arranged with a tool that operates the RCD and connected with a drum or riser housing having two connection elements shown in the connected position and an active seal shown in the sealed position.
Figure 3B is a sectional view taken along line 3B-3B of Figure 3A showing an ROV panel and an exemplary array of lines, such as strangulation lines, kill lines, reinforcement lines, umbilical lines and / or other lines, cables and conduits around the riser drum.
Figures 4A-4B consist of a cross-sectional elevation view of an RCD with three passive seals having a seal set arranged with a tool that operates the RCD and connected with a drum or riser housing having three connection elements shown in connected position, engaging the lower connection element with the sealing assembly and a duct or bypass line having a valve inside.
Figures 5A-5B consist of a cross-sectional elevation view of an RCD having three passive seals having a sealing set arranged with a tool that operates the RCD and sealed with a riser housing and the RCD connected with the riser housing having two connecting elements shown in the connected position and a duct or bypass line having a valve inside.
Figure 6A is a partial elevation cross-sectional view of an RCD that has a seal assembly with a seal from the mechanically extrusable seal assembly in the unsealed position, the seal assembly having two uncut cutting pins and an ratchet cut.
Figure 6B is a partial broken elevation cross-sectional view of the RCD of Figure 56A with the tool that operates the RCD shifted down from its position in Figure 6A to place the upper cutting pin of the seal assembly in the cutting position and to gradually advance the ratchet cut ring to extrude the seal from the seal assembly to the sealed position.
Figure 6C is a partial broken view in elevation in cross section of the RCD of Figure 6B with the tool that operates the RCD displaced up from its position in Figure 6B, with the upper cutting pin of the seal assembly being cut, but in its non-cut position, the ratchet cut ring cut to allow the seal of the seal assembly to move to the unsealed position and the connecting elements of the drum or riser housing shown in the unconnected position.
Figure 7A is a partial elevation cross-sectional view of an RCD that has a seal assembly with a seal assembly seal shown in the unsealed position, the seal assembly having upper, intermediate and lower cutting pins, a ring with ratchet or unidirectional locking and two split concentric C rings.
Figure 7B is a partial broken elevation view in cross section of the RCD of Figure 7A with the tool that operates the RCD shifted down from its position in Figure 7A, with the upper cutting pin of the seal assembly and the cutting pin bottom shown cut and the ratchet ring gradually rotated to extrude the seal from the seal assembly to the sealed position.
Figure 7C is a partial broken elevation view in cross section of the RCD of Figure 7B with the tool that operates the RCD displaced upwards from its position in Figure 7B, with the upper cutting pin of the sealing assembly and the cutting pin bottom cut, but in its non-cut position, the intermediate cut pin being cut to allow the seal of the seal assembly to move to the unsealed position while all connecting elements of the drum or riser housing remain in the connected position .
Figure 8A is a partial split elevation cross-sectional view of an RCD that has a seal assembly, with a seal assembly seal shown in the unsealed position and a motion loss connection from the connected RCD seal assembly. with a drum or riser housing, on the right side of the break line an upper cut pin and a lower cut pin arranged with a tool that operates the RCD both uncut and on the left side of the break line, the tool being operates the RCD shifted up from its position on the right side of the break line to cut the lower cut pin.
Figure 8B is a partial broken elevation view in cross section of the RCD of Figure 8A with the tool that operates the RCD displaced up from its position on the left side of the break line in Figure 8A, with the retainer of the lower connection element moved to the lower end of the motion loss connection and the unidirectional ratchet ring hinged upward to extrude the seal from the seal assembly.
Figure 8C is a partial broken elevation view in cross section of the RCD of Figure 8B with the tool that operates the RCD shifted down from its position in Figure 8B, the seal of the seal assembly being in the sealed position and the ring being in Separate C moved radially out of its concentric position to its position engaged with the shoulder.
Figure 8D is a partial broken elevation view in cross section of the RCD of Figure 8c with the tool that operates the RCD displaced up from its position in Figure 8C, so that a shoulder of the tool that operates the RCD engages with the ring in C broken radially inward.
Figure 8E is a partial broken elevation view in cross section of the RCD of Figure 8D with the tool that operates the RCD moved higher up from its position in Figure 8D, so that the C rings engaged with the shoulder cut the pin top cut to allow the seal of the seal assembly to move to the unsealed position after the top two connecting elements have been disconnected.
Figure 9A is a partial elevation cross-sectional view of an RCD that has a seal assembly with a seal assembly seal shown in the unsealed position, a seal assembly connection element in the connected position, the upper pins, intermediate and lower cutting are all uncut and a ratchet or unidirectional locking ring upper and lower, the RCD seal assembly arranged with a tool that operates the RCD, and connected with a riser drum that has three elements of connection shown in the connected position and a conduit or bypass line.
Figure 9B is a partial broken elevation view in cross section of the RCD of Figure 9A with the tool that operates the RCD shifted down from its position in Figure 9A, with the upper cutting pin cut and the lower ratchet ring rotated to extrude the seal from the seal assembly.
Figure 9C is a partial broken elevation cross-sectional view of the RCD of Figure 9B with the tool that operates the RCD shifted down from its position in Figure 9B, the lower cutting pin cut and the seal of the seal assembly displaced to the sealed position and the segments with the leaf spring moved radially out of their concentric position to their engaged position with the shoulder of the tool that operates the RCD.
Figure 9D is a partial broken elevation view in cross section of the RCD of Figure 9C with the tool that operates the RCD displaced up from its position in Figure 9C, so that the leaf spring segments engaged with the tool shoulder operating the RCD cut the intermediate cut pin to allow the sealing assembly latch to move to the disconnected position after the top two connecting elements are disconnected.
Figure 9E is a partial broken view in elevation in cross section of the RCD of Figure 9D with the tool that operates the RCD displaced further up from its position in Figure 9D, with the lower cutting pin being cut, but in its position not cut, the seal of the seal assembly in the disconnected position to allow the seal of the seal assembly to move to the unsealed position after the two upper connecting elements are disconnected.
Figure 10A is a partial elevation cross-sectional view of an RCD that has a seal assembly, analogous to Figure 4B, with the seal assembly seal shown in the unsealed position, a seal of the seal assembly shown in the connected position. , the top and bottom uncut pins and a unidirectional or locking ratchet ring, the bottom cut pin being placed between the tool that operates the RCD and the leaf spring segments, and a riser drum having three elements shown in the connected position and a conduit or bypass line.
Figure 10B is a partial broken view in elevation in cross section of the RCD of Figure 10A with the tool that operates the RCD displaced upwards from its position in Figure 10A, receiving the loss of motion connection from the seal assembly to the element retainer. lower connecting pin and the lower cutting pin cut to allow the lower segments with leaf spring to move inwards in a slot in the tool that operates the RCD.
Figure 10C is a partial broken elevation cross-sectional view of the RCD in Figure 10B with the tool that operates the RCD shifted downwards after it has moved further up from its position in Figure 10B to dislocate the element retainer lower connection to the lower end of the motion loss connection and the unidirectional or locking ratchet ring keeping the seal of the seal assembly in the sealed position and to move the upper spring leaf segments from their concentric position to their position engaged with the shoulder of the tool that operates the RCD.
Figure 10D is a partial broken elevation view in cross section of the RCD of Figure 10C with the tool that operates the RCD displaced upwards from its position in Figure 10C after being arranged in the well bore, so that the spring segments blades engaged with the tool shoulder cut the top cutting pin while the seal of the seal assembly is maintained in the sealed position after the two upper connecting elements have been disconnected.
Figure 10E is a partial broken view and cross-sectional elevation of the RCD of Figure 10D with the tool that operates the RCD further moved from its position in Figure 10D, so that the seam of the seal assembly can move to its disconnected position to allow the seal of the seal assembly to move to the unsealed position after the upper two connecting elements have been disconnected.
Figure 11 is a cross-sectional elevation view of an RCD arranged with a simple hydraulic connection set.
Figure 12 is a cross-sectional elevation view of an RCD arranged with a double hydraulic connection assembly.
Figure 13 is an elevation view of a RCD connected with a connection set (not shown) in a housing with a first umbilical line on the left side that extends from a first umbilical line drum and connected with the housing and a second umbilical line on the right side extending from a second umbilical line drum and secured with a set of valves (not shown) connected to accumulators, with a signal device in a retracted position below the accumulators.
Figure 14 is a schematic view of an acoustic control system that includes a surface control unit, an underwater control unit, a first acoustic signal device sustained below the sea level of a drum, and a second and third acoustic signal devices in the exploded view arranged with a set of valves and a multiplicity of subsea accumulators positioned with a subsea housing having an internal connection set.
Figure 15 is a schematic view of the accumulators and valve set in Figure 14 arranged with hydraulic lines, check valves, and sensors.
Figure 16 is a schematic view of the acoustic control system of Figures 14 and 15 with the set of valves and accumulators arranged on a semi-submersible floating platform positioned with an underwater riser and a set of BOP over a wellhead in view elevation.
Figure 17 is a cross-sectional elevation view of an RCD arranged with an underwater housing allowing drilling without any underwater riser.
Figure 18 is a cross-sectional elevation view of an RCD arranged with an underwater housing over a subsea BOP set allowing drilling without any subsea riser.
Figure 19 is an elevation view of an RCD in a dashed view connectable with a housing with accumulators releasably coupled with the housing with an accumulator compression ring, and a signal device disposed below the accumulators in a retracted position.
Figure 20 is the same as Figure 19 except for the signal device that is in an operational position.
Figure 21 is the same as Figure 19 except that the housing has been rotated 90 degrees around the vertical axis to show three operational accumulators and a receiving or compensating accumulator.
Figure 22 is a plan view of Figure 21 with the four accumulators attached to the housing with an accumulator compression ring and with the signal device moved from a retracted position, in dashed view, to an operational position.
Figure 23A is a schematic view of the accumulators and valve set in Figure 14 arranged with hydraulic lines, check valves and sensors.
Figure 23B is a schematic view of the accumulators and valve set of Figure 14 arranged with hydraulic lines, check valves and sensors.
A system and method for disconnecting and / or connecting RCD or other oil exploration device positioned with a connection set are described in general. In addition, a system and method for creating a seal and / or removing a seal from an RCD or other oil exploration device using an active seal is described. The connection set can be arranged with an underwater riser and / or an underwater housing. If there is a subsea riser, the connection set is intended to be placed below the tension lines or the tension ring that supports the top of the riser from the drilling structure or platform. An RCD may have an internal element rotating with respect to an external element around axial thrust bearings such as RCD Model 7875, available from Weatherford International of Houston, Texas and other RCDs proposed in the '181,' 171 and '774 patents. Although some types and sizes of RCD are shown in the modalities, other types and sizes of RCD are provided for all modalities, including RCDs with different numbers, configurations and orientations of passive seals, and / or RCDs with one or more active seals. It is also envisaged that the system and method can be used to operate these active seals.
In Figure 1, the drum or riser housing 12 is positioned with sections (4.10) of submarine riser. The submarine riser sections (4, 10) form part of an underwater riser, as described above in the Fundamentals of the Invention. The housing 12 is illustrated as being secured with pins (24, 26) to the respective sections (4, 10) of the subsea riser. Other means of attachment are provided. An RCD 2 with two passive separator seals (6, 8) rests inside the housing 12 and is connected to it using connection assemblies such as the first connection plunger 14 and second connection plunger 18, both of which can be actuated , as described in the '837 patent (see Figures 2 and 3 of the' 837 patent). The packer seal 22 active in the housing 12, shown in its uninflated and unsealed position, can be hydraulically expandable to a sealed position for sealing engagement with the outer diameter of the RCD 2 using the present invention.
The remote control panel 28 of the Remote Operated Vehicle (ROV) can be positioned with the housing 12 between protective flanges (30, 32) for the operation of the hydraulic connection pistons (14, 18) and active packer seal 22. An ROV 3 containing hydraulic fluid can be sent below sea level to connect to the ROV panel 28 to control operations of the housing 12 components. The ROV 3 can be controlled remotely from the surface. More specifically, by supplying the hydraulic fluid to different components using plug valves and other mechanical devices, connecting pistons (14, 18) and active seal 22 can be operated when feasible. Alternatively, or in addition for redundancy purposes, one or more hydraulic lines, such as umbilical line 5, can be sent from the surface to supply hydraulic fluid for remote operation of the connecting pistons (14, 18) and active seal 22 of the housing 12. Alternatively, or in addition to provide additional redundancy and safety, an accumulator 7 for the storage of hydraulic fluid can be activated remotely to operate the components of the housing 12 or to store fluid under pressure. It is envisaged that all three means for the hydraulic fluid can be provided. It is also envisaged that an ROV panel, an ROV, hydraulic lines and / or similar accumulator can be used with all the modalities of the invention.
The outer diameter of RCD 2 is smaller than the inner diameter of housing 12 or straight drilling. The first retainer element 16 and the second retainer element 20 are shown in Figure 1 after they have been moved from their first respective unconnected position to their second respective connected position. The RCD 2 may have a change in the outer diameter that occurs in the first retaining element 16. As shown in Figure 1, the upper outer diameter 9 of the RCD 2 may be larger than the lower outer diameter 31 of the RCD 2. Other configurations are provided for. of the outer surface of the RCD, including the fact that the RCD does not have a change in the outer diameter.
As shown in Figures 1 and IA, the upper outer diameter 9 of the RCD 2 above the second retainer element 20 and between the first retainer element 16 and the second retainer element 20 can have a plurality of vertical grooves 23. As shown in Figure IA, the second retainer element 20 may consist of a plurality of struts. The first retainer element 16 can also consist of a plurality of pins as the second retainer element 20. The retainer elements (16, 20) can be segmented locking fingers. Each of the retaining elements (16, 20) can consist of a broken ring or a C-shaped element, or each of them can consist of a multiplicity of broken ring segment or C-shaped elements. The retaining elements ( 16, 20) can be tilted radially outward. Each of the retaining elements (16, 20) can consist of mechanical interlocking elements, such as the tongue and groove type or the T slide type, for positive retraction. Other configurations are provided for the retaining elements.
The vertical grooves 23 along the outer surface of the RCD 2 allow fluid passages 235 when the catches 20 are in the connected position as shown in Figure 1A. The vertical grooves 23 allow the movement of fluids around the RCD 2 when the RCD 2 is moved inside the riser. Vertical grooves 23 are designed to prevent compression or the appearance of fluids in the riser below RCD 2 when RCD 2 is lowered or seated inside the riser and friction or a vacuum effect when RCD 2 is raised or removed from the riser .
Returning to Figure 1, the first retaining element 16 blocks the downward movement of the RCD 2 during settlement by contact with the locking shoulder 11 of the RCD, resulting from the change between the upper outer diameter 9 of the RCD and the lower outer diameter 31 of the RCD . The second retainer element 20 engaged the RCD 2 in a horizontal radial receiving groove 33 around the upper outer diameter 9 of the RCD 2 to tighten or compress the RCD 2 between the retainer elements (16, 20) to oppose rotation resistance. In their second connected positions, the retaining elements (16, 20) can also squeeze or compress RCD 2 radially inward. It is envisaged that the retainer elements (16, 20) can alternatively be moved to their positions connected radially inward and axially upward to tighten or compress the RCD 2 using retainer elements (16, 20) to counter rotational resistance.
As can now be understood, the RCD can be tightened or compressed axially upwards and downwards and radially inwards. In their first disconnected positions, the retaining elements (16, 20) allow a distance between the RCD 2 and the housing 12. In their second connected positions, the retaining elements (116, 20) lock and engage in a connectable way with RCD 2, respectively, to resist vertical movement and rotation. The modality shown in Figures 1 and IA for the external surface of RCD 2 can be used for all modalities shown in all Figures.
Although it is anticipated that frame 12 may have a body pressure level of 10,000 psi (68.95 MPa), other pressure levels are also expected. In addition, although it is envisaged that the opposite flanges (30, 32) of the housing may have an outside diameter of 39 inches (99.1 cm), other sizes are envisaged. The RCD 2 can be plugged in with a 21.250 inch (54 cm) hole 34 of subsea riser sections (4.10) with a 19.25 inch (48.9 cm) internal hole 12A of the housing 12. Other sizes are provided. It is also envisaged that the housing 12 may be positioned above a submarine diverter, such as a submarine diverter with an internal diameter of 59 inches (149.9 cm) or be an integral part of it. Other sizes are provided. The diverter will allow the fluid to move into the drill pipe and rise through the annulus to exit through the diverter opening below the bottom separator seal 8 and the same active seal 22. Although the active seal 22 is shown below the support assembly of the RCD 2 and below the connecting pistons (14, 18), it is envisaged that the active seal 22 can be positioned above the RCD support set and the connecting pistons (14, 18). All types of seals are provided, active or passive, as are known in the art. Although the active seal 22 is illustrated positioned with the housing 12, it is envisaged that the seal, active or passive, could instead be positioned with the outer surface of the RCD 2.
In the method, to establish a settlement for RCD 2, which can be an RCD with an external diameter of 18,000 inches (45.7 cm), the first retainer element 16 is activated remotely to the connected or loading position. The RCD 2 is then moved into the housing 12 until the RCD 2 is seated with the locking shoulder 11 of the RCD making contact with the first retaining element 16. The second retaining element 20 is then activated remotely with the supplied hydraulic fluid as discussed above for the connected position to engage with the RCD host groove 33, thus creating a compressive force on the outer surface of the RCD 2 to, among other benefits, resist torsion or rotation. More especially, the top chamfer on the first retainer element 16 is engaged with the shoulder 11 of the RCD. When the lower chamfer of the second retaining element 20 moves into the groove 33 on the outer surface of the RCD 2, the lower chamfer "pinches" the RCD between two retaining elements (16, 20) to apply a compressive force on the RCD 2 to resist twisting or rotation. The active seal 22 can then be expanded with the supplied hydraulic fluid as discussed in this document to produce the seal against the lower outer surface of RCD 2, to seal the gap or annulus between RCD 2 and the housing 12.
The operations of the housing 12 can be controlled remotely through the ROV fluid supplied to the control panel 28, with the hydraulic line 5 and / or accumulator 7. Other methods are envisaged, including the activation of the second retainer element 20 simultaneously with the active seal 22. Although not shown in Figure 1, a bypass channel or line, such as an internal bypass channel 68 shown in Figure 22 and an external bypass line 186 shown in Figure 4A, an external bypass line or a similar internal bypass channel provided with a valve can be used in the embodiment of Figure 1 or in any other embodiment of the present invention. The operation of a bypass line with a valve will be discussed in detail below in association with Figure 2.
Secondary or safety plungers (1000, 1002) can move respective primary plungers (14, 18) to their disconnected positions if the hydraulic system fails to move the primary plungers (14, 18). The secondary pistons (1000, 1002) cannot operate independently of each other.
Returning to Figure 2, an RCD 40 with three passive separator seals (41, 46, 48) is positioned with the drum or riser housing 72 with the first retainer element 56 and the second retainer element 60, both of which are activated by the hydraulic pistons connection sets (54, 58). The first retainer element 56 blocks the movement of the RCD 40 when the locking shoulder 43 engages with the retainer element 56 and the second retainer element 60 is positioned with the receiving groove or groove 45 of the RCD. The operations of the housing 72 components can be controlled remotely using ROV 61 connected with the ROV control panel 62 positioned between flanges (74, 76) and additionally protected by the protection element 64. Alternatively, or additionally, as treated above, housing components 74 can be operated by hydraulic lines and / or accumulators. The separator seal of RCD 41 has an inverted position in relation to the other separator seals (46, 48) to, among other reasons, resist resistance to the "suction down" of drilling fluids during a total or partial loss of circulation. Such a loss of circulation could result in the riser collapsing if there is no fluid in the riser to withstand resistance to external forces impacting the riser. For RCD 40 in Figure 2, and for similar RCD separator seals modalities in the other Figures, it is envisaged that two opposite separator seals, such as the separator seals (41, 46), can constitute an integral or continuous seal and not two separate seals.
The outer diameter of RCD 40 is less than the inner diameter of housing 72, which can be 19.25 inches (48.9 cm). Other sizes are provided. Although the riser housing 72 has a body pressure level of 10,000 psi (68.95 MPa), other pressure levels are expected. The retaining elements (56, 60) can consist of a multiplicity of struts or a C-shaped element, although other types of elements are provided. Active seal 66, shown in an unexpanded and unsealed position, can be expanded to seal in engagement with RCD 40 using the present invention. Alternatively, or in addition, an active seal can be positioned above the RCD support assembly and connection assemblies (54, 58). Housing 74 is illustrated as being secured with pegs (50, 52) to subsea riser sections (42, 44). As discussed above, other means of fixation are provided. Although it is envisaged that opposite housing flanges (74, 86) may have an outside diameter of 45 inches (114.3 cm), other sizes are envisaged. As can be understood, the RCD 40 can be fixed in a connected manner with the perforation of the housing 72. It is also provided that the housing 74 can be positioned with a submarine diverter with an internal diameter of 59 inches (139.9 cm).
The system shown in Figure 2 is generally analogous to the system shown in Figure 1, except for the internal bypass channel 68 which, as stated above, can be used with any of the modalities. A valve 78, such as a gate valve, can be positioned within bypass channel 68. Two end plugs 70 can be used after internal bypass channel 68 has been manufactured, as shown in Figure 2, for communication over the sealing with atmospheric pressure outside the well hole. Bypass channel 58 with gate valve 78 acts as a check valve in kick or blowout conditions of the well. Gate valve 78 can be operated remotely. If unfavorable weather conditions are predicted, for example, valve 78 could be closed with the riser controlled in a sealable manner and the offshore platform can be driven to a safer location. In addition, if the riser was lifted with the RCD in place, valve 78 could be opened to allow fluid to pass outside the RCD 40 and out of the riser below the housing 72 and RCD 40. Under such conditions it can be The fluid is allowed to flow through the bypass channel 68, around the RCD 40, through the first end 80 of the bypass channel and the second end 82 of the bypass channel, bypassing the sealed RCD 40 with the housing 72. As an alternative to the internal bypass channel 68, it is envisaged that an external bypass line, such as bypass line 186 in Figure 4A, can be used with the embodiment of Figure 2 and any other embodiment.
In Figure 3A, the drum or riser housing 98 is illustrated connected by means of threaded nuts and axles 116 to the subsea riser section 100. An RCD 90 having a seal assembly 92 is positioned together with a tool that operates the RCD 94 with the housing 98. The connection formations of the seal assembly 118 can be positioned in J-shaped hook grooves 96 in the tool that operates the RCD 94, so that the tool that operates the RCD 94 and the RCD 90 are moved together in the drilling column through the underwater riser and the housing 98. Other means of attachment are provided as are known in the art. A tool that operates the RCD, such as tool 94, can be used to position an RCD with any type of drum or riser housing. The RCD 90 is seated together with the housing 98 with the first retainer element 106 and compressed with the second retainer element 110, the two being remotely actuated by the respective hydraulic pistons in the respective connection assemblies (104, 108). The first retainer element 106 blocks the shoulder 105 of the RCD and the second retainer element 110 is positioned with the second formation or groove 107 of the RCD.
The ROV control panel 114 can be positioned with the housing 98 between the upper and lower protective protrusions 112 (only the lower protrusion is shown) to protect panel 114. Other means of protection are provided. Although it is envisaged that the opposite flanges 120 of the housing (only the lower flange is shown) of the housing 98 may have an outside diameter of 45 inches (114.3 cm), other sizes are envisaged. The outer diameter of the RCD 90 is less than the inner diameter of the housing 98. The retaining elements (106, 110) may consist of a plurality of struts or a C-shaped element. The active seal 102, shown in a expanded or sealed position, sealingly engages with RCD 102. After the RCD 90 has been sealed, as shown in Figure 3A, the tool that operates the RCD 94 can be disengaged from the RCD seal set 92 and continue to move with the drill column going down the riser for drilling operations. Alternatively, or in addition, an active or passive seal can be positioned on the RCD 90 and not on the housing 98 and / or it can be positioned both above and below the RCD support set or connection sets (104, 108). As an alternative to the embodiment shown in Figure 3A, a seal assembly, such as seal assembly 92, can be positioned above the RCD support assembly or connection assemblies (104, 108), to engage with a tool that operates the RCD. The alternate seal assembly can be used either to house a seal, such as seal 102, or else it can be used as the portion of the RCD to be sealed by a seal on a housing as in the embodiment shown in Figure 3A.
In general, the lines and cables extend radially out of the riser, as shown in Figure 1 of the '181 patent, and male and female elements of the lines and cables can be plugged together as the riser sections are connected between itself. Returning to Figure 3B, an exemplary rerouting or placement of these lines and cables is shown outside the frame 98 within the design criteria of the inner diameter 130 as the lines and cables pass through the frame 98. The exemplary lines and cables can include 1.875 inch (4.7625 cm) OD 134 multiplex cables, 2.375 x 2.000 (6.0325 x 5.08 cm) rigid conduit lines 136, 5, 563 x 4.5 mud reinforcement line (14.13002 x 14.13002 cm), a 7 x 4.5 kill line (17.78 x 14.13002 cm), a 7 x 4.5 (17.78 x 14) choke line , 13002 cm), a 7.5 x 6 (19.05 x 15.24 cm) mud return line 144, and a 7.5 x 6 (19.05 x 15, 24 cm). Other sizes, lines (such as umbilical lines already treated) and cables and configurations are provided. It is also envisaged that an ROV or accumulator (s) can be used to replace some of the lines and / or conduits.
It is anticipated that a subsea riser segment would produce the insertion of the male or pin end of its riser tubular segment lines and cables with the female or box end of the tubular segment line and cable of the lower riser. The lines and cables, as shown in Figure 3B, can also be inserted or plugged with riser tubular segment lines and cables that extend radially outward, so that they can be plugged against each other when connecting the cable segments. riser. In other words, the lines and / or cables shown in Figure 3B are routed along the vertical elevation profile outside the frame 98 to avoid protrusions in the frame, such as panel 114 and protrusion 112, but the lines and cables are aligned radially to outside to allow them to be connected with their respective lines and cables from the contiguous riser segments. Although section 3B-3B is only shown in Figure 3A, an exemplary similar layout of the ROV panel, lines and cables as shown in Figure 3B can be used with either mode.
An external bypass line 186 with gate valve 188 is shown and discussed below according to Figure 4A. Although Figure 3A does not show a bypass line and gate valve, it is anticipated that the embodiment in Figure 3A may have a bypass line and gate valve. Figure 3B shows an exemplary arrangement of a gate valve 141 with actuator 143 if used in accordance with Figure 3A. A similar arrangement can be used for the embodiment in Figure 4A and other embodiments.
In Figures 4A-4B, the drums or riser housings (152A, 152B) are fixed between sections of the subsea riser (154, 158) with respective pegs (156, 160). Housing 152A is attached to housing 152B using pins 157. A protective element 161 can be positioned with one or more of the pins 157. (three openings in the protective element, for example, to receive three pins) to protect a panel of ROV that is not shown. An RCD 150 with three passive separator seals (162, 164, 168) is positioned with drums or riser housings (152A, 152B) with the first retainer element 172, second retainer element 176 and third retainer element or seal assembly retainer 182, all of which are activated by respective hydraulic pistons in their respective connection assemblies (170, 174, 180). The retaining elements (172, 175, 182) in the housing 152B, as shown in Figure 4B, have been moved from their respective first positions or disconnected positions to their respective second positions or connected positions. The first retainer element 172 blocks the shoulder 173 of the RCD and the second retainer element 176 is positioned with the receiving formation or groove 1175 of the RCD. The 152B frame operations can be controlled remotely using any ROV connected with a ROV containing hydraulic fluid and control panel, hydraulic lines and / or accumulators, all of which have already been described, but are not shown for clarity The figure.
The RCD seal assembly, generally indicated at 178, for the RCD 150 and the tool that operates the RCD 184 are analogous to the seal assembly and the tool that operates the RCD shown in Figures 10A-10E and will be described in detail below in association with these Figures. The separator seal of RCD 162 is inverted in relation to the other separator seals (164, 168). Although the RCD seal assembly 178 is shown to be below the RCD support assembly and below the first and second connection assembly (170, 174), a seal assembly may alternatively be positioned above the RCD support assembly. RCD and the first and second connection set (170, 174) for all modes.
External bypass line 186 with valve 188 can be fixed with housing 152 with pins (192, 196). Other means of attachment are also provided. A similar bypass line and valve can be positioned with any modality. Unlike bypass channel 68 in Figure 2, bypass line 186 in Figures 4A-4B is outside and is releasable from the housings. Bypass line 18 6 with gate valve 188 acts as a check valve in kick or blowout conditions in the well. Gate valve 188 can be operated remotely. Thus, if unfavorable weather conditions are predicted, valve 188 could be closed with the controllable seal riser and the marine platform could be moved to a safer location.
In addition, when the riser with the RCD installed is raised, valve 188 could be opened to allow fluid to pass outside the RCD 150 and out of the riser below the housing 152B and RCD 150. Under conditions where the extrusable seal of the sealing assembly 198 is in a sealing position (as described below in detail in relation to Figures 10A-10E), fluid may be allowed to flow through the bypass line 186, bypass the RCD 150, cross the first end of the bypass line 190 and the second end of bypass line 194, thus passing outside the RCD 150 sealed with frame 152B. As an alternative to the external bypass line 186, it is envisaged that an internal bypass channel such as bypass channel 68 in Figure 2 can be used according to Figures 4A-4B and any other embodiment.
Referring to Figures 5A-5B, the drum or riser housing 202 is illustrated as being attached to subsea riser sections (204, 28) with respective pins (206, 210). An RCD 200 that has three passive seals (240, 242, 244) and a seal assembly 212 is positioned with a tool that operates the RCD 216 used for positioning the RCD 200 with the housing 202. The connection formations 214 the set Sealing lines can be positioned in J 218 hook-shaped grooves in the tool that operates the RCD 216 and the tool that operates the RCD 216 and RCD 200 moved together in the drilling column through the underwater riser. The RCD 200 is fitted with the housing 202 with the first retainer element 222 and connected with the second retainer element 226, both of which are operated remotely by respective hydraulic pistons in the respective connection assemblies (220, 224). The first retainer element 222 blocks the shoulder of RCD 223 and the second retainer element 226 is positioned with the receiving groove or groove of RCD 225.
The active packer seals upper 202A, intermediate 202B and lower 202C can be activated using the present invention to seal the annulus between housing 202 and RCD 200. The upper active seal 202A and the lower active seal 202C can be sealed together to protect connection assemblies for the 202C seal. It is also envisaged that the bottom active seal 202C can be sealed first to seal the pressure inside the riser below the bottom seal 202C. The upper active seal 202A can then be pressure sealed to act as a plunger to prevent residues and debris from coming into contact with connecting elements (220, 224). Other methods are envisaged. Sensors (219, 229, 237) can be positioned with the housing 202 between the seals (202A, 202B, 202C) to detect the borehole parameters, such as pressure, temperature and / or flow. Such measurements can be useful in determining the effectiveness of the seals (202A, 202B, 202C) and can indicate whether a seal (202A, 202B, 202C) is not sealing properly or has been damaged or has failed.
It is also envisaged that other sensors can be used to determine the relative difference in rotation speed (RPM) between any of the passive RCD seals (240, 242, 244), such as seals 240 and 242, for example. For the modality shown in Figures 5A-5B, as well as for all other modalities, a data information collection system, such as DIGS, provided by Weatherford, associated with a PLC can be used to monitor and / or reduce the relative sliding of the sealing elements (240, 242, 244) with the drill string. It is provided that the rotations per minute (RPM) of the sealing elements (240, 242, 244) can be measured in real time. If one of the sealing elements (240, 242, 244) is on an independent internal element and rotates at a different speed than that of another sealing element (240, 242, 244), then this may indicate a slip of the sealing elements in relation to tubular. In addition, the rotation speed of the sealing elements can be compared with that of the measurement on the upper drive (not shown) or on the rotating plate on the drilling floor.
The information obtained from all sensors, including the sensors (219, 229, 237) can be transmitted to the surface for processing with a CPU through an electrical line or cable positioned with hydraulic line 5 shown in Figure 1. An ROV can also be used to access information on the ROV 228 panel for processing or on the surface or by the ROV. Other methods are envisaged, including remote access to information. After the RCD 200 is connected and sealed, as shown in Figure 5B, the tool that operates the RCD 216 can be disengaged from the RCD 200 and continue to move with the drill string going down the riser for drilling operations.
The ROV control panel 228 can be positioned with the housing 200 between two protective protrusions 230 to protect the panel 228. The outer diameter of the RCD 200 is smaller than the inner diameter of the housing 202. The retaining elements (222, 226 ) can consist of a multiplicity of struts or a C-shaped element. The external bypass line 232 with valve 238 can be fixed to housing 202 with pins (234, 236). Other means of fixation are provided. Bypass line 232 with a gate valve 238 acts as a check valve when kick or blowout conditions occur in the well. Valve 238 can be operated remotely.
Referring to Figure 6A, the RCD 250 having a seal assembly, generally designated at 286, is shown to be connected to a drum or riser housing 252 with the first retainer element 256, second retainer element 260, and third retainer element or seal assembly retainer 264 of the respective connection assemblies (254, 258, 262) in their second respective or connected / seated positions. The first retainer element 256 blocks the RCD shoulder 257 and the second retainer element 260 is positioned with the RCD host formation or groove 259. An external bypass line 272 is positioned with the housing 252. An ROV panel 266 is arranged with the housing 252 between two protective protrusions 268. The seal assembly 286 comprises an extension element or extender 278 of RCD, the tool element operating the RCD 274, the retainer receiving element 288, the seal 276 of the seal assembly, the first upper cutting pins or pins 282, the second lower cutting pins or pins 280, and the graduated cutting ring or element graduated cutter 284. Although two upper cutting pins 282 and two lower 280 are shown for this modality and others, it is anticipated that there may be only one upper cutting pin 282 and one lower 280 or that there may be a multiplicity of cutting pins upper 282 and lower 280 of different sizes, different metallurgy and different cutting levels. Other mechanical cutting devices as are known in the art are also provided.
The seal 27 6 of the seal assembly can be connected with the locking shoulder 290 of the tool element and with the retainer receiving element 288, such as by epoxy. A lip retainer is provided in one of the two elements or in the two tool elements 274 and host retainer 288 that fits with a formation (s) on the seal 276. This retaining formation, analogous to the formation 320 shown and / or described according to Figure 7A, allows seal 276 to be connected with tool element 274 and / or retainer housing element 288. A combination of clamping and mechanical connection as described above can be used. Other fixation methods are provided. The fixing means shown and discussed for use with the extrudable seal 276 can be used with any extrudable seal shown in any embodiment.
The extrudable seal 276 in Figure 6A, as well as all similar extrudable seals shown in all RCD seal assemblies in all modalities, can be produced from a monolithic or integral piece of material, or alternatively, it can be produced from of two or more segments of different materials that are formed together with structural supports, such as a wire mesh or metal supports. Different material segments can have different properties. If the seal 276 is produced, for example, in three segments of elastomers such as an upper, intermediate and lower segment, when observed in an elevated cross section, the upper and lower segments may have certain properties that enhance their ability to contain between them or compress a more extrusable intermediate segment. The intermediate segment can be formed differently or have different properties that allow it to be extruded laterally when compressed to produce a better seal with the riser housing. Other combinations and materials are also foreseen.
The seal assembly 286 is positioned with the tool that operates the RCD 270 with lower cutting pins 280 and shoulder 271 of the tool that operates the RCD. After the tool that operates the RCD is mounted on the drill string, the tool that operates the RCD 270 and RCD 250 are moved together from the surface down through the submarine riser to frame 252 in the seating position shown in Figure 6A. In one method, it is predicted that before the RCD 250 is lowered into the housing 252, the first retainer element 256 would be in the seating position, and the second retainer element 260 and third retainer element 264 would be in their disconnected positions. The shoulder 257 of RCD could contact the first retaining element 256, which would block the downward movement. The second retainer element 260 would then be moved to its connected position by engaging with the RCD host formation 259, which, as already discussed above, would tighten the RCD between the first retainer element 256 and the second 260 to counter rotation resistance. The third retainer element would then be moved to its position connected with the retainer host element 288, as shown in Figure 6A. After seating, the seal 276 of the seal assembly can be extruded as shown in Figure 6B. It should be understood that the downward movement of the tool that operates the RCD and the RCD can be performed using the weight of the drill string. For all the modalities of the invention shown in all the Figures, it is envisaged that the connection position indicator system, such as one of the modalities proposed in the '837 patent or in the' 724 publication, can be used to determine whether the connecting pistons, such as the connection assemblies (254, 258, 262) of Figure 6A are in their connected or disconnected positions. It is anticipated that a programmable logic controller (PLC) having a comparator can compare hydraulic fluid values or parameters to determine the positions of the connections. It is also envisaged that an electrical switching system, a mechanical valve system and / or a proximity sensor system can be positioned with a retaining element. Other methods are envisaged.
It is envisaged that the seal assembly 286 may be detachable from RCD 250, as in locations (277A, 277B). Other attachment locations are provided. The seal set 286 can be threaded with the RCD 250 in places (277A, 277B). Other types of connections are provided. The release seal set 286 can be removed for repair and / or replacement with a different seal set. It is envisaged that the replacement seal assembly would accommodate the same vertical distance between the first retainer element 256, the second retainer element 260 and the third retainer element 264. All seal assemblies in all other embodiments in the Figures can be detached so analogous to its RCDs.
Figure 6B shows the adjustment position used to adjust or extrude the seal 276 from the seal assembly to produce the seal with housing 252. To adjust the extrusable seal 276, the tool that operates the RCD 270 is moved down from the position of settlement shown in Figure 6A. This downward movement produces the cutting of the upper cutting pin 282, but not the lower cutting pin 270. The downward movement also moves the ratchet cutting ring 284 upwards. As can now be understood, the lower cutting pin 280 has a higher cutting and ratcheting force than the upper cutting pin 282 and the ratchet cutting ring 284, respectively, in relation to the retainer receiving element 288 and then maintains relative position. Therefore, the ratchet cut ring 284 allows downward movement of the operating tool 274. The operating tool 270 pulls the tool element 275 down. It is anticipated that the force required to fully extrude the seal 276 is less than the cutting intensity of the upper cutting pin 282.
When the upper cutting pin 282 is cut, there is sufficient force to fully extrude seal 276. Tool element 274 will move downward after upper cutting pin 282 has been cut. The locking shoulder 292 of the tool element prevents further downward movement of the tool element 274 when the shoulder 292 contacts the upwardly facing locking shoulder 294 of the RCD extension element 278. However, it is anticipated that the seal 276 will be fully extruded before the locking shoulder 292 of the tool element 274 comes into contact with the upwardly facing shoulder 294. The ratchet cutting ring 284 prevents the tool element 274 from moving coming back up after the tool element 274 has moved down.
The shoulder 290 of the tool element 274 compresses and extrudes the seal 276 against the retainer element 288 which is held in place by the third retainer element 264. During adjustment, the ratchet cut ring 285 allows the lock element tool 274 is gradually rotated downwards with minimal resistance and without cutting ring 284. After seal 276 has been adjusted as shown in Figure 6B, the tool that operates the RCD 270 can continue to descend through the riser for drilling operations, cutting the lower cutter pin 280. Ratchet cutter ring 284 prevents tool element 274 from moving upward after lower cutter pin 280 has been cut, thereby maintaining seal 276 of the extruded seal assembly, as shown in Figure 6B, during drilling operations. As can now be understood, for the embodiment shown in Figures 6A-6C, the weight of the drill string causes the operating tool 270 to move downward to seat the seal 276 of the seal assembly.
As shown in the view of Figure 6B, it is provided that the shoulder 290 of the tool element 274 can be tilted with a positive slope to improve the extrusion and seal of the seal 27 6 with the housing 252 in the sealed position. It is also envisaged that the upper edge of retainer housing element 288, which can be connected to seal 276, may have a negative slope to improve the extrusion and seal of seal 276 in the sealed position with housing 252. The slope described above of the elements adjacent to the extrudable seal can be used with all modes that have an extrudable seal. For Figure 6A and other embodiments with extrusable seals, it is provided that if the distance between the surface facing out of the non-extruded seal 276 as shown in Figure 6A and the surface of the inner hole of the riser housing 252, when extruded seal 276 comes into contact when extruded, is 0.75 inches (1.91 cm) to 1 inch (2.54 cm) so a 2000 to 3000 sealing force could be provided. Other distances or intervals and other forces sealing are provided. It should be understood that the greater the distance or the gap, the less the sealing force of the seal 276. It must also be understood that the composition of the extrudable seal material will also affect its sealing force.
Figure 60 shows the housing 252 in the fully released position for removal or removal of the RCD 250 from the housing 252. After drilling operations are complete, the operating tool 270 can be moved upwards through the riser towards the housing 252. When the boss 271 of the operating tool comes into contact with tool element 274, as shown in Figure 6C, the first, second and third retaining element (256, 260, 264) must be in their connected positions, as shown in Figures 6A and 6B. The shoulder 271 of the operating tool then pushes the tool element 274 upward, cutting the teeth of the ratchet cutting ring 284. As can now be understood, the ratchet cutting ring 284 allows the ring to be rotated in one direction, but makes a cut when moved in the opposite direction after sufficient force is applied. The tool element 274 moves upward until the locking shoulder 296 facing upward from the tool element 274 contacts the locking shoulder 298 facing downward from the extension element 278. The pin openings used to contain the upper cutting pins 282 and lower 280 must be at the same height before the pins are cut. Figure 6C shows the upper cutting pins 282 and lower 280 cut as being aligned. Again, the pins could be contiguous in the opening for the pins or be spaced apart and equidistant, as desired, and depending on the pin being used.
When the tool element 274 moves upwards, the locking shoulder 290 of the tool element moves upwards, pulling the seal 276 of the sealing assembly in relation to the fixed retainer element 288, retained by the third retainer element 264 in the connected position. The seal 276 is preferably extended to have substantially its initial shape, as shown in Figure 6C. The retaining elements (256, 260, 264) can then be moved to their first or disconnected positions as shown in Figure 60, and the RCD 250 and the operating tool 270 are removed together displaced up on the housing 252.
Referring to Figure 7A. The RCD 300 and its seal assembly, designated in general with 340, are shown connected to the drum or riser housing 302, with the first retainer element 304, the second retainer element 308, and the third retainer element or retainer assembly seal 324 of the respective connecting pistons (306, 310, 322) in their second respective positions or connected / seated positions. The first retainer element 304 blocks the shoulder 342 of RCD and the second retainer element 308 is positioned with the second host formation 344 of RCD. An external bypass line 346 is positioned with the housing 302. An ROV panel 348 is arranged with the housing 302 between a protective protrusion 350 and flange 302A. The sealing assembly 340 comprises the extension element 312 of the RCD, the tool element 314 of the RCD, the tool element 330, the retaining element 326, the seal 318 of the sealing assembly, upper cutting pins 316, intermediate cutting pins 332, lower cutting pins 334, ratchet or locking ring 328, internal split C ring 352, and external split C ring 354. The internal C ring 352 has shoulder 358. Tool element 314 has locking lugs facing downwards (368, 360). Tool element 330 has upward facing lug 362 and downward facing lug 364. Retaining element retainer 326 has downward facing lug 366. Extension element 312 has downward facing lug 370.
Although two upper cutting pins 316, two lower 334 and two intermediate 332 are shown, it is anticipated that there may be only one upper cutting pin 316, one lower 334 and one intermediate 332, or, as discussed above, there may be a multiplicity upper cutting pins 316, lower 334 and intermediate 332. Other mechanical cutting devices are also provided which are known in the art. The seal 318 of the seal assembly can be connected to the RCD tool element 314 and to the retainer receiving element 325, by epoxy, for example. A lip-shaped retainer formation 320 on tool element 314 of the RCD fits with a formation on seal 318 to allow seal 318 to be pulled by tool element 314 of RCD. Although a similar lip-shaped formation is not shown, it can be used to connect seal 318 with retainer retainer 326. A combination of mechanical fastening and attachment as described above can be used.
The seal set 340 is positioned with the tool that operates the RCD 336 with lower cutting pins 334, shoulder of the operating tool 356 and concentric C rings (352, 354). The operational tool 336 and the RCD 30 are moved together from the surface through the submarine riser descending into the housing 302 in the seated position shown in Figure 7A. In one method, it is predicted that before the RCD 300 is lowered into the housing 302, the first retainer element 304 would be in the seated position and the second retainer element 308 and the third 324 would be in their unconnected positions. The RCD shoulder 342 would be blocked by the first retainer element 304 to block the downward movement of the RCD 300. The second retainer element 308 would then be moved to its engaged position engaging the RCD host formation 344 which would tighten the RCD between the first element retainer 304 and the second 308. The third retainer element 324 would then be moved to its position connected with the retainer receiving element 326 as shown in Figures 7A-7C. After seating is complete, the seal 318 of the seal assembly can be adjusted or extruded.
Figure 7B shows the adjustment position used to adjust or extrude the seal 318 of the seal assembly with the housing 302. To adjust the extrusable seal 318, the tool that operates the RCD 336 is moved down from the seating position shown in Figure 7A, so that the shoulder 365 of the tool operating the RCD 336 pushes the inner C-ring 352 downward. The inner C-ring 352 contacts as locking shoulder 362 of tool element 330, and pushes tooling element 330 down until locking shoulder 364 of tool element 330 contacts locking shoulder 3366 of the retainer receiving element 326, as shown in Figure 7b. The outer C-ring 354 then moves inwardly into the groove 358 of the inner C-ring 352 as shown in Figure 7B. The downward movement of the tool that operates the RCD 336 first cuts the lower cutting pins 334 and after the inner C-ring 352 pushes the tool element 330 down, the upper cutting pins 316 are cut, as shown in Figure 7B. The intermediate cutting pins 332 are not cut. As can now be understood, the intermediate cutting pins 332 have a higher shear strength than the upper cutting pins 316 and the lower cutting pins 334. The intermediate cutting pin 332 pulls the RCD tool element 314 down until the downward facing lug 368 of the RCD tool element 314 contacts the upward facing lug 370 of the RCD extension element 312. The ratchet or locking ring 328 allows the tool element 330 to be moved gradually with respect to the retainer receiving element 326. Like the ratchet cut ring 284 of Figures 6A-6C, the ratchet or locking ring 328 of Figures 7A-7C allows for gradual movement. However, unlike the ratchet cut ring 284 of Figures 6-6C, the ratchet or locking ring 328 of Figures 7A-7C is not designed to cut when tool element 330 moves upwards, but the ring ratchet or locking 328 on the contrary resists the upward movement of the adjacent element to preserve the relative positions.
The shoulder 360 of the tool element 314 of the RCD compresses and extrudes the seal 318 against the retainer element 328 which is fixed by the third retainer element 324. After the seal 318 is adjusted, as shown in Figure 7B, the tool that operates the RCD 336 can continue down the riser for drilling operations. Ratchet or locking rings 328 and intermediate cutter pin 332 prevent tool element 330 and tool element 314 from RCD from moving upward, thus retaining the seal 318 of the extruded seal assembly, as shown in Figure 7B, during drilling operations. As can now be understood, for the embodiment shown in Figures 7A-7C, the tool that operates the RCD 336 is moved downwards to adjust the seal 318 of the seal assembly, being pulled to be released. The weight of the drill string can be relied on for downward force.
Figure 7C shows the tool that operates the RCD 336 displaced upwards inside the housing 302 after drilling operations, to release the seal 318 and then to recover the RCD 300 from the housing 302. The shoulder 370 of the tool that operates the RCD contacts the inner C-ring 352. The first, second and third retaining elements (304, 308, 324) are in their connected positions, as shown for the first 304 and the third 324 retaining elements in Figure 7C. The inner C-ring 352 supports the outer ring C 354, the outer C-ring 354 rests on shoulders of the RCD tool element 314 for cutting the intermediate cutting pins 332. The ratchet or locking ring 328 holds the tool element 330. As can now be understood, the ratchet or locking ring 328 allows movement of the tool element 330 in one direction, but opposes resistance to movement in the opposite direction. The RCD tool element 314 moves upward until the locking shoulder 361 of the RCD tool element 314 contacts the locking shoulder 371 of the extension element 312. The openings used to contain the upper cutting pins 316 and below 334 must be at substantially the same height before starting with the pins.
When the RCD tool element 314 moves upward, the RCD tool element locking shoulder 360 moves upward by pulling the seal 318 from the seal assembly with the formation of the lip-shaped retainer 320 and / or the connected connection, since the retainer receiving element 326 is fixed by the third retaining element 324 in the connected position. The retaining elements (304, 308, 324) can then be moved to their first positions or disconnected positions and the RCD 300 and the tool that operates the RCD 336 together are pulled onto the housing 302.
Referring to Figure 8A, the RCD 380 and its seal assembly, indicated in general with 436, are shown connected to the drum or riser housing 382 with the first retainer element 386, the second retainer element 390, and the third retainer or retainer element of the sealing assembly 398 of the respective connecting pistons (388, 392, 400) in their respective second connected positions. The first retainer element 386 blocks the shoulder 438 of RCD and the second retainer element 390 is positioned with the host formation 440 of RCD. An external bypass line 384 is positioned with housing 382. A valve can be positioned with line 384 and any additional bypass lines. An ROV panel 398 disposed with the housing 382 between a protective ledge 396 and protective element 381 positioned with flange 382A, similar to the protective element 1611 in Figure 4A. Returning to Figure 8A, the seal assembly 436 comprises the RCD extension element 402, tool element 418, retainer receiving element 416, seal assembly seal 404, upper cutting pins 422, lower cutting pins 408 , ratchet locking ring 420, lower cutting pin retaining ring or third C 410 ring, first C or inner ring 428, and second C or outer ring 430. The inner C ring 428 has groove 432 for the outer C-ring 430 settles when the tool that operates the RCD 412 is moved below its position shown on the left side of the broken line in Figure 8A as will be described in detail with reference to Figure 8C. Tool element 4181 has locking shoulder 426. Retaining housing element 416 has locking shoulder 424 and motion loss connection or groove 436 for a motion loss connection with the third retaining element 398 in its connected position as shown in Figure 8A. The extension element 402 has a lip-shaped retainer formation 406 for positioning with a corresponding formation on the seal 404.
Although two upper cutting pins 422 and two lower cutting pins 408 are shown for this mode, it is anticipated that there may be only one upper cutting pin 422 and one lower 408, or as discussed above, there may be a multiplicity of upper cutting pins 422 and below 408 for this embodiment of the invention. Other mechanical cutting devices are also provided, as is known in the art. The seal 404 of the seal assembly can be connected to the extension element 402 and the retainer receiving element 416, for example by epoxy. A lip-shaped retainer formation 406 on RCD extension member 402 fits with a corresponding formation on seal 404 to allow seal 404 to be pulled by extension member 402. Although not shown, a similar lip formation can be used to connect seal 404 with retainer retainer element 416. A combination of mechanical fastening and attachment as described above can be used. Other methods of fixation are provided for.
The seal set 436 is positioned with the tool that operates the RCD 412 with lower cutting pins 408 and third ring in C 410, shoulder 414 of the tool that operates the RCD and concentric inner and outer C rings (428, 430). The tool that operates the RCD 412 and RCD 380 are moved together from the surface through the submarine riser under the frame 382 in the seating position shown on the right side of the break line in Figure 8A. In one method, it is predicted that before the RCD 380 is lowered into the housing 382, the first retaining element 386 would be in the connected or seating position, and the second retaining element 390 and the third 386 would be in their disconnected positions. The RCD shoulder 438 would contact the first retainer element 386, which would then block the downward movement of the RCD 380. The second retainer element 390 would then be moved to its connected position by engaging with the RCD 440 host formation to compress the RCD 380 between the first retaining elements 386 and the second retaining elements 390 to oppose rotation resistance. The third retainer element 398 would then be moved to its position connected with the retainer host element 416, as shown in Figure 8A.
On the left side of the break line in Figure 8A, the tool that operates the RCD 412 has moved upwards, cutting the lower cutting pins 408. The shoulder 426 of the tool element 418 pushes the retaining ring 410 of the cutting pin bottom down to slot 413 of the operating tool 412. The C-ring 410 has an inward slope and contracts inward from its position shown on the right side of the break line, due to the diameter of the operating tool 413. The lock 414 of the operating tool 412 came into contact with the locking shoulder 424 of the retainer receiving element 416.
Figure 8B shows the adjustment position to mechanically adjust or extrude the seal 404 of the seal assembly with the housing 382. To adjust the extrudable seal 404, the operating tool is moved up from the seating position, shown on the right side of the Figure 8A to the position shown on the left of Figure 8A. The locking shoulder 414 of the operating tool 412 pushes the retainer receiving element 416 upward. The motion loss groove 434 of the retainer receiving element 416 allows the retainer receiving element 416 to move upward until it is blocked by the downward facing locking 426 of the tool element 418 and the locking shoulder facing away from above 426 of the retainer receiving element 46, as shown in Figure 8C.
The ratchet or locking ring 420 allows for the gradual displacement of the retainer receiving element 416 with the tool element 418. It should be understood that the tool element 418 does not move downwards to adjust the seal 404 in Figure 8C. Like the ratchet ring and lock 328 of Figures 7A-7C, the ratchet or lock ring 420 retains the positions of its respective elements.
The retainer receiving element 416 compresses and extrudes the seal 404 against the extension element 402 of the RCD which is connected and secured by the first retainer element 386. After the seal 404 is adjusted as shown in Figure 8B, the operational tool 412 can start to move down as shown in Figure 8C through the riser for drilling operations. The ratchet or locking ring 420 prevents the retainer receiving element 416 from moving downwards, maintaining the seal 404 of the extruded seal assembly as shown in Figure 8b during drilling operations. As can now be understood, for the modality shown in Figures 8A-8e, in contrast to the modalities shown in Figures 6A-6C and 7A-7C, the operational tool 412 is moved upwards to extrude the seal 404 from the assembly sealing.
In Figure 8C, the operating tool 412 began to move downward through the housing 382 from its position in Figure 8B to begin drilling operations after the seal 404 has been extruded. The RCD 380 is still connected to the housing 382. The shoulder 440 of the operating tool contacts the inner C-ring 428 by pushing it downwards. The outer C-ring 430, which has a radially inward inclination, moves from its concentric position into the groove 432 in the inner C-ring 428 and the inner C-ring 428 moves outward enough to allow the shoulder 440 of the operating tool moves downward through the internal C-ring 428. The operating tool can then travel downwards with the drill string for drilling operations.
Figure 8D shows the RCD operating tool 412 returning from drilling operations and moving upward into the housing 382 for the RCD 380 removal process. The shoulder 442 of the operating tool 412 supports the inner C-ring 428 as shown in Figure 8D. Figure 8E shows the seal assembly 436 and the housing 382 in the RCD withdrawal position. The first retainer elements 386 and second retainer elements 390 are in their first unconnected positions. The operating tool 412 moves upwards and the shoulder 442 of the operating tool supports the inner C-ring 428 in its upward movement, the latter supporting the outer C-ring 430. The outer C-ring 430 then supports the movement of the element extension 402 of the RCD disconnected upwards. The RCD 380 that has the extension element 402 of RCD can move upwards, since the first retaining element 386 and the second 390 are disconnected. The lip-shaped formation 406 of the extension member 402 pulls the seal 404 upwards. The seal 404 can also be connected with the extension element 402. The retainer retaining element 416 remains supported against the third retainer 398 in the connected position. It is envisaged that the seal 404 may also be connected with the retainer receiving element 416 and / or may also have a lip-shaped connection analogous to the formation 406 in the extension element 402. In all embodiments of the invention, when if an RCD is removed or released from the housing, the operating tool is pulled or moves upward into the housing.
Referring to Figure 9A, RCD 444 and its seal assembly 466 are shown connected to the riser drum or housing 446 with the first retainer element 448, the second retainer element 452, and the third retainer element or retainer element d462 of the assembly for sealing the respective connecting pistons (450, 453, 464) in their respective second connected positions. The first retainer element 448 blocks the shoulder 492 of the RCD and the second retainer element 452 is positioned with the host formation 494 of the RCD. An external bypass line 456 is positioned with housing 446. An ROV panel 458 is arranged with housing 446 between a supporting ledge 460 and flange 446A. The seal assembly 466 comprises RCD or extension element 470. The RCD tool element 490, the tool element 482, the retaining element 496, the sealing element 476, the seal 480 of the seal assembly, the upper cutting pins 472, the intermediate cutting pins 474, the lower cutting pins 484, the seal of the sealing assembly 478, the ratchet or upper locking ring 488, the ratchet or lower locking ring 486, the ring in Inner C or first ring in C 498 and outer segments 500 with two leaf springs 502. It is anticipated that there may be a multiplicity of segments 500 held together radially around inner ring C 498 by leaf springs 502. Segments 500 with leaf springs 502 they constitute a radially expandable element which is forced to contract radially inwards. It is also envisaged that there can be only one leaf spring 502 or a plurality of leaf springs 502. It is also envisaged that an inner C-ring can be used instead of outer segments 500 with 502 leaf springs. An external C-ring can also be used with leaf springs. The internal C-ring 498 is arranged between the shoulders (518, 520) of the operating tool. The inner C-ring 498 has a groove 504 for the seating of external segments 500 when the operating tool 468 is moved downwards from its position in Figure 9A, as will be described in detail with reference to Figure 9C.
The ratchet or upper locking ring 488 is arranged in the groove 524 of the extension element 470 of the RCD. Although two upper cutting pins 472, two lower 484 and two intermediate 474 are shown for this modality, it is anticipated that there can be only one upper cutting pin 472, a lower cutting pin 484 and an intermediate cutting pin 474 or, depending on above, there may be a multiplicity of upper cutting pins 472, lower 484 and intermediate 474. Other mechanical cutting devices that are known in the art are also provided. The seal 480 of the seal assembly can be connected with the sealing element 476 and the retaining element 496, by epoxy, for example. A lip-shaped retainer formation 506 on seal element 476 fits with a corresponding formation on seal 480 to allow seal 480 to be pulled by seal element 476, as will be described in detail below with reference to Figure 9E. Although not shown, a similar lip-shaped formation can be used to connect seal 480 with retainer retainer 496. A combination with mechanical fastening connection can be used, as described above. Other methods of fixation are provided for.
The sealing set, generally indicated as 466, is positioned with the RCD operating tool 468 with lower cutting pins 484, shoulder of the operating tool 508, internal C-ring 498, and segments 500 with leaf springs 502. The tool Operational 468 and RCD 444 are moved together from the surface through the submarine riser descending on the housing 446 in the seating position shown in Figure 9A. In one method, it is predicted that before the RCD 444 is lowered into the housing 446, the first retaining element 448 should be in the seated position and the second retaining element 452 and the third 462 would be in their disconnected positions. The shoulder 492 of the RCD would be in contact with the first retainer element 448 to block the downward movement of the RCD 444. The second retainer element 452 would then be moved to its connected position engaging the RCD host formation 494, which would tighten the RCD between the first retaining element 448 and the second 452 to oppose rotation resistance. The third retainer element 462 would then be moved to its position connected with the retainer element 496, as shown in Figure 9A.
Figure 9B shows the first stage of the adjustment position used to mechanically adjust or extrude seal 480 from the seal assembly with housing 446. To adjust extrusable seal 480, operating tool 468 is moved down from the seated position shown in Figure 9A. The lower cutting pin 484 pulls the tool element 482 down with the operating tool 468. The shoulder of the tool element 518 then holds the inner C-ring 498 down in relation to the outer segments 500 immobilized with the leaf springs 502 As with the ratchet or locking ring 328 of Figures 7A-7C, the ratchet or lower locking ring 486 allows the downward movement of the tool element 482 while resisting the upward movement of the tool element 482. Similarly , the ratchet or upper locking ring 488 allows the downward movement of the RCD tool element 490 while resisting the upward movement of the RCD tool element 490. However, as will be treated below with reference to Figure 9D, the ratchet ring or upper lock 488 is positioned in the slot 524 of the extension element 470, allowing the movement of the ratchet ring or upper lock 488.
The RCD tool element 490 is pulled down by the intermediate cutting pins 474 arranged with the tool element 482. The downward movement of the tool element 482 cuts through the upper cutting pins 472. As can now be understood, the intensity of cutting of the upper cutting pins 472 is less than the cutting intensities of the intermediate cutting pins 474 and of the lower cutting pins 484. Tool element 482 moves downwards until its downward facing locking shoulder 514 comes into contact with the locking shoulder 516 upward from the retainer receiving element. The retaining latch 478 of the sealing assembly pulls the sealing element 475 down until its downward facing shoulder 510 comes into contact with the upward facing shoulder 512 of the extension element. The lock 478 may consist of a C-ring with an inwardly tilting radius. Other devices are envisaged. The seal 462 of the seal assembly is connected, securing the retainer retainer 496. The seal 480 of the seal assembly is extruded or adjusted as shown in Figure 9B. The ratchet or lower locking ring 486 resists upward movement of tool element 482, and the lock 478 resists upward movement of sealing element 476, thus maintaining seal 480 of the extruded seal assembly, as shown in Figure 9B, during drilling operations.
Figure 9C shows the final stage of seal adjustment 480. The operating tool 468 is moved below its position in Figure 9B using the weight of the drill string to cut the lower cut pin 484. As can now be understood, the lower cutting pin 484 has a lower cutting intensity than intermediate cutting pin 474. The shoulder 518 of the tool that operates RCD pushes the inner C-ring 498 down and the outer segments 500 can move into the groove 504 of the internal C-ring 498, as shown in Figure 9C. The operating tool 468 can then continue to descend with the drill column for drilling operations, leaving the RCD 444 sealed with the housing 446. As will now be understood, for the mode shown in Figures 9A-9E, the operating tool 468 is moved down to adjust the seal of the seal set 480. The weight of the drill string can be relied on for the downward force.
Figure 9D shows the operating tool 468 moving inside the housing 336 after drilling operations for the first stage of disengagement or release of the seal 480 and, consequently, the removal of the RCD 444 from the housing 446. The shoulder 520 of the operating tool supports the inner C-ring 498. The third retaining element462 is in its connected position. The inner C-ring 498 supports by pushing the outer segments 500 upwards by the shoulder in the groove 504, and the outer segments 500 support the RCD tool element 490 by pushing it upwards, cutting the intermediate cutting pins 474. The ratchet or upper lock 488 moves upwards in slot 524 of the RCD extension element 470 until it is blocked by the shoulder 526 of the extension element 470. The retaining pad of the seal assembly 478 is allowed to move inward or retract into slot 522 of tool element 490 of the RCD. Although not shown in Figures 9E-9E, the first retainer element 448 and the second retainer element 452, shown in Figure 9A, are moved to their first disconnected positions. It is also provided that the two retaining elements, the first 448 and the second 452, or one of them, can be moved to their disconnected positions before the movement of the operating tool 468 shown in Figure 9D.
Referring to Figure 9E, the final stage for unsealing seal 480 is shown. The operating tool 468 is moved up from its position in Figure 9D and the shoulder of the operating tool 520 supports the internal C-ring 498 upwards. The inner C-ring 498 supports the outer segments 500 arranged in the slot 504 of the inner C-ring 498 by pushing them upwards. The outer segments 500 support the tool element 490 of the RCD by pushing it upwards. Since the ratchet or upper locking ring 488 had previously come into contact with the shoulder 526 of the extension element 470 in Figure 9D, the ratchet or upper locking ring 488 now supports the extension element 47 0 of the RCD by pushing it towards upwards through the shoulder 526. The extension element 470 of the RCD can move upwards along with ord 444, since the first retaining element 448 and the second retaining element 452 are in their disconnected positions. The upwardly facing shoulder 512 of the extension element 470 pushes the downwardly facing shoulder 510 of the sealing element 476 upward, and the sealing element 476 in turn stretches the sealing 480 upward through the lip-shaped formation. 506 and / or connection with seal 480.
The third retainer element 462 keeps the retainer element 496 and the end of the seal 480 immobilized, since the seal 480 is connected and / or mechanically attached to the retainer element 496. The retainer lock 478 of the seal moves along slot 522 of RCD tool element 490. The seal 480 is preferably extended until it has substantially its initial shape, as shown in Figure 9E, with the openings in the operating tool 4468 and in the tool element 482 now being intended to contain the lower cutting pins 484 that were previously cut, are at the same height as when the lower cutting pin 484 was not cut. The retaining element of the seal assembly or third retaining element 4622 can then be moved to its first or disconnected position, allowing the tool operating RCD 468 to lift RCD 444 to the surface.
Referring to Figure 10A, RCD 530 and its seal assembly 548 are shown connected to the drum or riser housing 532 with first retainer element 536, second retainer element 540 and third retainer element 544 of the respective connecting pistons (538, 542, 5466) in their respective second connected positions. The first retainer element 536 blocks the shoulder 582 of RCD and the second retainer element 540 is positioned with the host formation 584 of RCD. An external bypass line 534 is positioned with the housing 532. The sealing assembly, generally indicated at 548, comprises extension element 550 from RCD, tool element 580 from RCD, tool element 560, seal retainer 554, seal 570 of the seal assembly, upper cutting pins 578, lower cutting pins 558, segments 556 provided with leaf springs 586 holding the lower cutting pins, ratchet or locking ring 562, inner C-ring 564, outer segments 566 with leaf springs 568, and retaining latch 576 of the seal assembly. It is envisaged that the C-rings can be used instead of the segments (566, 556) with the respective leaf springs (568, 586), or that the C-rings can be used with leaf springs. The shoulder 600 of the tool element rests on segments 556 of lower cutting pins. The inner C-ring 564 has groove 572 for the seating of outer segments 566 when the operating tool 552 is moved as described in relation to Figure 10C and shown therein. The inner C-ring 562 supports the operating tool shoulder 588. The retainer retaining element 554 has a locking shoulder 590 on the loss of motion connection or groove 592 for a loss of motion connection with the third retaining element 544 on the its connected position, as shown in Figure 10A.
Although two upper cutting pins 578 and two lower cutting pins 558 are mastered, it is anticipated that there may be only one upper cutting pin 578 and one lower cutting pin 558 or, as discussed above, that there may be a multiplicity of pins upper cutting pins 578 and lower cutting pins 558. Other mechanical cutting devices as are known in the art are also provided. The seal 570 of the seal assembly can be connected with the extension element 550 and with the retainer receiving element 554, for example epoxy. A lip-shaped retention formation 574 on extension member 550 of the RCD fits the corresponding formation on seal 570 to allow seal 570 to be pulled by extension member 550. Although not shown, a similar formation in shape of lip can be used to connect seal 570 with retainer retainer 554. A combination of mechanical fastening and attachment as described above can be used. Other fixation methods are also provided for.
The sealing set, generally indicated at 548, is positioned with the RCD operating tool 552 with the lower cutting pins 558 and segments of the lower cutting pins 556, the operating tool shoulder 588, the inner C ring 564, and the outer segments 566 with leaf springs 568. The lower cutting pin segments 556 are arranged on the surface 594 of the operating tool that has a larger diameter than the slot 596 adjacent to the operating tool. The operational tool 522 and the RCD 530 are moved together from the surface through the submarine riser descending into the housing 532 in the seated position shown in Figure 10A. In one method, it is predicted that before the RCD 530 is lowered into the housing 532, the first retaining element 536 would be in the seated position, and the second retaining element 540 and the third 544 would be in their disconnected positions. The RCD cam 582 would be blocked by the first retainer element 536, which would block the downward movement of the RCD 530. The next retainer element 540 would then be moved to its connected position by engaging the RCD host formation 584 which would tighten the RCD 530 between the first retaining element 536 and the second 540 to oppose resistance to rotation. The third retainer element 544 would then be moved to its position connected to the retainer retainer element 554 in connection with loss of movement or groove 592, as shown in Figure 10A. After the settlement is complete, the extrusion process of seal 570 from the seal assembly can begin, as shown in Figures 10B-10C.
In Figure 10B, the operating tool 552 has moved upward, the locking shoulder 600 of the tool element 560 pushed the segments that hold the lower cutting pins 556 down from the surface 594 of the operating tool to the slot 596 for the operating tool. Leaf springs 586 cause segments 556 to contract radially inward. The lower cutting pin 558 was cut by the movement of segments 556.
To continue with the adjustment or extrusion of seal 570, operating tool 552 is further moved up from its position shown in Figure 10B. The final adjustment position of seal 570 is shown in Figure 10C, but in Figure 10C, the operating tool 552 has already been moved upwards from its position in Figure 10B and then is shown moving down in Figure 10C with the drill string for drilling operations. To adjust the seal 570 as shown in Figure 10C, the operating tool 552 moves from its position in Figure 10B and the shoulder 598 of the operating tool holds the retainer receiving element 554 upward until it is blocked by the shoulder 600 of the holding element. tool 560. The ratchet or locking ring 562 allows for unidirectional upward movement of retainer receiving element 554 with respect to tool element 560. Like the ratchet or locking ring 328 of Figures 7A-7C, the ratchet ring or locking 562 resists upward movement of tool element 560.
The motion loss or groove connection 592 of the retainer receiving element 554 allows the retainer receiving element 554 to move upward until it is blocked by the third retainer 544 contacting the shoulder 590 at one end of the groove 592, as shown in Figure 10C. Retaining element 554 mechanically compresses and extrudes seal 570 against RCD extension element 550, which, as shown in Figure 10A, is connected securely by the first retainer element 536. After seal 570 has been adjusted with the upward movement of the operating tool 552 from its position shown in Figure 10B, the inner C-ring 564 and the outer segments 566 will be concentrically arranged, as shown in Figure 10B. The operating tool 552 can then be moved downwards with the drill string for drilling operations. With this downward movement, the cam 588 of the operating tool supports the inner C-ring 564 by pushing it downwards and the outer segments 566 with their leaf springs 568 will move into the groove 572 in the inner C-ring 564 in position shown in Figure 10C. The operating tool 552 then, as described above, continues to descend out of the housing 530 for drilling operations. The ratchet or locking ring 562 resists downward movement of retainer retainer 554, thus maintaining seal 570 of the extruded seal assembly, as shown in Figure 10C during drilling operations. As will now be understood, for the mode shown in Figures 10A-101E, as in the mode shown in Figures 8A-8E, and unlike the modes shown in Figures 6A-6C, 7A-7C and 9A-9E, the operational tool is displaced upward for mechanical adjustment or extrusion of the seal from the seal assembly.
Figure 10D shows the RCD operating tool 552 moving up and into the housing 532, returning after drilling operations to the start of the RCD 530 withdrawal process. When the locking shoulder 602 of the operating tool 552 holds the inner C-ring 564, as shown in Figure 10D, the first retainer elements 536 and the second retainer elements 540 are preferably in their first disconnected positions. It is also envisaged that the retaining elements 536, 540 may be disconnected after the operating tool 552 is in the position shown in Figure 10D, but before the position shown in Figure 10E. The shoulder 612 of the groove of the inner C-ring 572 supports the outer segments 566 by displacing them upwards. The outer segments 566, in turn, support the tool element 580 of the RCD by pushing it upwards. The RCD tool element 580, in turn, moves upward until its upward facing locking shoulder 608 is blocked by the downward facing shoulder 610 of the RCD extension element 550. The upward movement of the tool element 580 of the RCD, as shown in Figure 10D, allows the retraction of the lock 57 6 of the seal assembly into the slot 606.
Referring now to Figure 10E, the operating tool 552 continues to move upward from its position in Figure 10D while continuing to support the inner C-ring 564 with the shoulder 602 of the operating tool. The outer segments 566 continue to support the tool element 58 0 of the RCD, so that the latch 57 6 of the seal assembly moves along the slot 606 until it contacts the shoulder 604 at the end of the slot 606 of the RCD tool. The lock 576 may consist of a C-ring or other similar device with an inwardly tilt. The locking shoulder 608 of the RCD tool element 580 supports the locking shoulder 610 of the RCD extension element 550 in its upward movement. The RCD 530 which has an extension element RCD 550 moves upwards, since the first retaining elements 536 and the second retaining elements 540 are disconnected. The lip-shaped formation 574 of the extension element 550 pulls and stretches the seal 570 upward. The seal 570 can also be connected with the extension element 550. The retainer retaining element 554 supported on the shoulder 590 is blocked by the third retainer 544 in the connected position. It is envisaged that retainer retaining element 554 may also have a lip-shaped formation analogous to formation 574 on extension element 550 and be connected to further restrict the two ends of seal 570. After seal 570 has been detached or released, the third retainer element 544 can be moved to its disconnected position and the operating tool 552 can be moved up to the surface together with the RCD 530.
For all modalities in all Figures, it is provided that the drum or riser housing with the RCD disposed inside it can be positioned with the top of the riser or adjacent to it, at any intermediate location along the length of the riser, or on or adjacent to the ocean floor, such as through a conductive housing similar to that shown in the '774 patent or through the BOP assembly similar to that shown in Figure 4 of the' 171 patent.
In Figure 11, the RCD 100 'is arranged in a simple hydraulic connection set 240'. Figure 11 is a cross-sectional view of a single diverter casing section, riser section or other applicable tubular borehole section (hereinafter referred to as "casing section") and a simple hydraulic connection set for better illustrate the rotary control device 100 '. As shown in Figure 11, a connection set indicated separately at 210 'is attached to a housing section 200' with dowels. Although only two dowels 212A 'and 212B' are shown in Figure 11, any number of dowels and any desired arrangement of dowel positions can be used to provide the desired fixing and sealing of connection set 210 'to the housing section 200'. As shown in Figure 11, the housing section 200 'has a single outlet 202' for connection to a diverter conduit 204 ', shown in broken lines; however, other numbers of outlets and conduits can be used with the 115 'and 117' diverter conduits. Again, this conduit 204 'can be connected to a choke. The size, shape and configuration of the housing section 200 'and the connection set 210' are exemplary and illustrative only, and other sizes, shapes and configurations can be used to allow connection of the connection set 210 'to a riser. In addition, while the hydraulic connection set is shown to be connected to a nipple, the connection set can be connected to any conveniently configured section of a wellhead tubular or riser.
A seating formation 206 'of the housing section 200' engages with a shoulder 208 'of the rotary control device 100', limiting movement in the well of the rotary control device 100 'when positioning the rotary control device 100'. The relative position of the rotary control device 100 'and the housing section 200' and the connection set are exemplary and illustrative only, and other relative positions can be used.
Figure 11 shows connection set 210 'connected to rotary control device 100'. A retaining element 218 'extends radially into the connection set 210', engaging with a connection formation 216 'on the rotary control device 100', connecting the rotary control device 100 'with the connection set 210' and consequently with housing section 200 'attached to connection set 210'. In some embodiments, retainer element 218 'may have a "C-shape", which can be compressed to a smaller diameter to engage with connection formation 216'. However, other types and shapes of retaining rings are provided. In other embodiments, the retaining element 218 'may consist of a multiplicity of lock, key, pin or slide elements, spaced from one another and positioned around connection assembly 210'. In embodiments in which the retaining element 218 'consists of a multiplicity of lock or key elements, the lock or key elements can optionally be held in place by springs. Although a single retaining element 218 'has been described herein, a plurality of retaining elements 218' can be used. The retaining element 218 'has a sufficient cross-section to positively engage with the connection formation 216' and sufficiently to limit the axial movement of the rotary control device 100 'and still engage with the connection assembly 210'. An annular piston 22 0 'is shown in a first position in Figure 11, where the piston 220' locks the retaining element 218 'in the radially inward position to connect with the rotary control device 100'. The movement of the plunger 220 'from a second position to the first position compresses or moves the retainer element 218' radially inward to the engaged or connected position shown in Figure 11. Although it is shown in the Figure in the form of an annular piston 220 ', the plunger 220 'can be implemented in the form of a multiplicity of separate plungers, for example, arranged around the connection assembly 210'.
When the plunger 220 'moves to a second position, the retainer element 218' can expand and move radially outwardly to disengage from the rotary control device 100 'and disconnect the rotary control device 100' from connection set 210 '. The retainer element 218 'and the connection formation 216' can be formed in such a way that a predetermined upward force applied on the rotary control device 100 'will propel the retainer element radially outwardly to disconnect the rotary control device 100'. A second plunger 222 'or auxiliary plunger can be used to urge the first plunger 220' into the second position to disconnect the rotary control device 100 ', providing a safety disengagement capability. The shape and configuration of the plungers 220 'and 222' are exemplary and illustrative only and other shapes and configurations can be used.
The hydraulic holes 232 'and 234' and the corresponding channels drilled with pistols allow a hydraulic actuation of the piston 220 '. Increasing the relative pressure in the orifice 232 'causes the plunger 220' to move to the first position connecting the rotary control device 100 'to the connection set 210' with the retaining element 218 '. Increasing the relative pressure in the orifice 234 'causes the plunger 220' to move to the second position, allowing the rotary control device 100 'to disconnect allowing the retaining element 218' to expand and move and disengage from the device 100 'rotary control. Connecting the hydraulic lines (not shown in the Figure for clarity) to the holes 232 'and 234' allows a remote actuation of the piston 220 '.
The second annular plunger 222 'or auxiliary plunger is also shown to be actuated hydraulically using the hydraulic orifice 230' and its corresponding pistol-drilled channel. Increasing the relative pressure in the orifice 230 'causes the plunger 222' to push or push the plunger 220 'to the second position or disconnected position, if the direct pressure through the orifice 234' stops displacing the plunger 220 'by any reason.
The hydraulic holes 230 ', 232' and 234 'and their corresponding channels shown in Figure 11 are exemplary and illustrative only and other numbers and arrangements of the hydraulic holes and channels can be used. In addition, other techniques are provided for remote actuation of pistons 220 'and 222', different from hydraulic actuation, to remotely control connection set 210 '.
Thus, the rotary control device illustrated in Figure 11 can be positioned, connected, disconnected and removed from the housing section 200 'and connection set 210' without having to send maintenance personnel below the rotary table in the pool to connect and disconnect the rotary control device 100 '.
A variety of seals are used among the various elements described in this document, such as sealing joints and sealing rings, known to those skilled in the art. Each plunger 220 'preferably has an internal and an external seal to allow fluid pressure to build up and force the plunger in the direction of the force. Similarly, seals can be used to seal the joints and retain the fluid, preventing it from leaking between the various components. In general, these seals will not be discussed in more detail in this document.
Seals 224A 'and 224B', for example, seal rotary control device 100 'against connection assembly 210'. Although two seals 224A 'and 224B' are shown in Figure 11, any number and arrangement of seals can be used. In one embodiment, seals 224A 'and 224B' are Parker Polypak® seals of 1/4 inch cross section from Parker Hannifin Corporation. Other types of seal can be used to provide the desired seal.
In Figure 12, RCD 100 'is arranged in a double hydraulic connection set 300'. Figure 12 illustrates another modality of a connection set, generally indicated at 300 ', which is a double hydraulic connection set. As with the simple connection set 210 'illustrated in Figure 11, the plunger 220' compresses or displaces the retaining element 218 'radially inward to connect the rotary control device 100' to the connection set 300 '. The retainer element 218 'connects with the rotary control device 100' in a connection formation known as an annular groove 320 ', in an outer housing of the rotary control device 100' in Figure 12. The use and shape of the groove ring 320 'are exemplary and illustrative only and other connection configurations and format formats can be used. The double hydraulic connection set includes pistons 220 'and 222' and retainer element 218 'of the simple connection set mode of Figure 11 as a first connection subset. The different modalities of the double hydraulic connection set mentioned below insofar as they refer to the first connection set can also be applied to the simple hydraulic connection set in Figure 11.
In addition to the first connection subset comprising the pistons 220 'and 222' and the retaining element 218 ', the dual hydraulic connection set 300' illustrated in Figure 12 proposes a second connection subset comprising a third piston 301 'and a second retaining element 304 '. In this embodiment, the connection set 300 'is itself connectable to a housing section 310', shown as a riser nipple, allowing for a remote positioning and removal of the connection set 300 '. In such an embodiment, the housing section 310 'and the double hydraulic connection set 300' are preferably paired with each other, with different configurations of the double hydraulic connection set implemented to fit different configurations of the housing section 310 '. A common modality of the rotary control device 100 'can be used with a multitude of modalities of the double hydraulic connection set, alternatively, different modalities of the rotary control device 100' can be used with each modality of the double hydraulic connection set 300 'and housing section 310'.
As with the first connection subset, the plunger 302 'moves to a first connection position or position. However, the retaining element 304 'instead of expanding radially outwards, in comparison with the inward expansion, of the connection assembly 300' for a connection formation 311 'in the housing section 310'. Shown in Figure 12 in the form of an annular groove 311 ', the connection formation 311' can be any passive formation suitable for engagement with the retaining element 304 '. As with plungers 220 'and 2.2.2.' , the shape and configuration of the plunger 302 'is exemplary and illustrative only and other formats and configurations of the plunger 302' can be used. In some embodiments, retainer element 304 'may have a "C-shape" that can be expanded to have a larger diameter to engage with connection formation 311'. However, other types and shapes of retaining rings are envisaged. In other embodiments, the retaining element 304 'may consist of a plurality of locking elements, keys, pins or slides, positioned around the connection set 300'. In embodiments where the retaining element 304 'consists of a multiplicity of locking elements or keys, the locking elements or keys can optionally be spring-loaded. Although a single retaining element 304 'is described herein, a plurality of retaining elements 304' can be used. The retaining element 304 'has a sufficient cross-section to positively engage with the connection formation 311' to limit the axial movement of the connection set 300 'and to continue engaging with the connection set 300'.
The shoulder 208 'of the rotary control device 100' in this embodiment rests on a seating formation 308 'of the connection set 300', limiting downward movement or movement in the well of the rotary control device 100 'on the connection set 300' . As stated above, connection set 300 'can be manufactured for use with a specific housing section, such as housing section 310', designed to fit with connection set 300 '. On the other hand, the connection set 210 'of Figure 11 can be manufactured in standard sizes for use with several generic housing sections 200', which do not need any modification to be used with the connection set 210 '.
Cables (not shown) can be connected to rings or rings 322A 'and 322B' mounted on the rotary control device 100 'to allow positioning of the rotary control device 100' before and after installation in a connection set. The use of cables and eyelets for positioning and removing the rotary control device 100 'is exemplary and illustrative, and other positioning devices and numbers and arrangements of the eyebolts or other fixing devices can be used as will be discussed below.
Similarly, the connection set 300 'can be positioned in the housing section 310' using cables (not shown) connected to eyes 306'A and 306B ', mounted on an upper surface of the connection set 300'. Although only two such eyelets 306A 'and 306B' are shown in Figure 12, other eyelet numbers and arrangements can be used. In addition, other techniques for cable assembly and other techniques for positioning the unconnected connection set 300 'can be used as will be discussed below. As may be desired by a platform operator, connection set 300 'may be positioned or removed from housing section 310' with or without rotary control device 100 '. Therefore, if the rotary control device 100 stops disconnecting from the connection set 300 'when desired, the connected rotary control device 100' and connection set 300 ', for example, can be disconnected from the housing section 310' and removed from a unit for repair or replacement. In other embodiments, a shoulder of an operating tool, tool joint 250A 'of a column 250' of piping or any other shoulder in a tubular that could engage with a lower separation rubber 246 'can be used for positioning the locking device. rotary control 100 instead of the eyes and cables mentioned above. An exemplary tool joint 250A 'of a pipe column 260' is shown on a dashed line in Figure 11.
As best shown in Figure 11, the rotary control device 100 includes a support assembly 240 '. The support assembly 240 'is analogous to the Model 7875 rotary control device from Weatherford-Williams, now available from Weatherford International, Inc. of Houston, Texas. Alternatively, the rotary control devices models 7000, 7100, IP-1000, 7800, 8000/9000, and 9200 or the Weatherford RPM SYSTEM 300 ™, now available from Weatherford International Inc. It is preferable that the rotary control device 240 'with two seals spaced apart, such as separation rubbers, is used to provide a redundant seal. The main components with Support Set 240 'are described in U.S. Patent No. 5,662,181, now owned by Weatherford / Lamb, Inc., which is incorporated herein in full by reference for all purposes. In general, the support assembly 240 'includes an upper rubber pot 242' which is sized to receive an upper separation rubber or an internal element seal 244 '; however, top rubber pot 242 'and seal 244' can be omitted, if desired. It is preferred that the lower separation rubber or inner element seal 246 'is connected to the upper seal 244' by the inner element of the support assembly 240 '. The outer element of the support assembly 240 'is rotatably connected to the inner element. In addition, seals 244'and 246 'can be passive separating rubber seals as shown, or active seals as is known to those skilled in the art.
In the form of a simple hydraulic connection set 210 'as shown in Figure 11, a lower accumulator may be necessary, as the hoses and lines cannot be used to maintain the pressure of the hydraulic fluid in the lower portion of the support set 100' . In addition, an accumulator allows the bearings (not shown) to be self-lubricating. An additional accumulator can be provided in the upper portion of the connection set 100 'if desired.
Referring to Figure 13, RCD 1022 is connected to frame 1020. While in operation, frame 1020 would be disposed under the sea with an underwater riser or directly with the wellhead or the BOP assembly if there is no riser. The 1020 housing has an internal connection set to connect to the RCD 1022 or other oil exploration device. The first electrohydraulic umbilical line 1024 is connected at one end with the housing 1020 and can provide primary control for the connection set in the housing 1020. The second electrohydraulic umbilical line 1026 is connected at one end with a set of valves (not shown) and can also provide control for the connection set in the housing 1020. The accumulators (1023, 1035) are removably attached to the housing 1020 with the accumulator compression ring 1021. There can be four accumulators as shown in Figure 21. Other numbers of accumulators are also predicted. Returning to Figure 13, the signal device 1031 is in a retracted position below the accumulators (1023, 1025). The valve set can be switched between allowing fluid to flow through the second electro-hydraulic umbilical line 1026 and allowing fluid to flow from the accumulators (1023, 1025), as discussed in detail below. Umbilical drums (1028, 1030) store respective umbilical lines (1024, 1026). Although an RCD 1022 is shown, it is envisaged that any oil exploration device can be connected to the 1020 housing, including, but not limited to, protective sleeves, support assemblies without any separation rubber, separation rubbers, cable devices, and any other oil exploration device to be used with a well bore.
In Figure 14, the acoustic control system 1007 can include surface control unit 1004, subsea control unit 1010, first acoustic signal device 1006, and second caustic signal device 1008. A third acoustic signal device 1008A is also provided , as well as additional acoustic signal devices. The second and third acoustic signal devices, the subsea control unit 1010 and the valve set 1012 can be arranged directly with one or more operating accumulators 1016, one or more receiving or compensating accumulators 1062, on the housing 1014, but are shown in an exploded view in Figure 14 for clarity. Housing 1014 contains an internal connection set to connect with an oil exploration device such as an RCD.
It is envisaged that subsea components, including the second and third acoustic signal devices (1008, 1008A), subsea control unit 1010, valve assembly 1012, operational accumulators 1016, and receiving accumulator 1062, can be housed on a frame or pod frame around frame 1014. The second and third acoustic signal devices (1008, 1008A) can be supported on articulated arms or extensions that depart from the frame structure, although other means of fixation. The first signal device 1006 can be stored below the sea surface by drum 1005. The first signal device 1006 can transmit acoustic signals as controlled by the surface control unit 1004, and the second acoustic device 1008 can receive acoustic signals and transmit them to submarine control unit 1012.
The first and second acoustic signal devices (1006, 1008) can be transceivers to provide two-way communication, so that the two devices (1006, 1008) can transmit and receive communication signals between themselves as they are controlled by their respective control units (1004, 1010). The devices (1006, 1008) can also be transceivers connected with transducers. The third signal device 1008A can also be a transceiver or a transceiver coupled with a transducer.
Acoustic control systems can be available from Kongsberg Maritime AS in Horten, Norway; Sonardyne Inc. of Houston, Texas; Nautronix of Aberdeen, Scotland; and / or Oceaneering International Inc. of Houston, Texas, among others. An acoustic actuator can be used in the acoustic control system such as that available from ORE offshore from West Wareham, MA, among others. It is anticipated that the 1008 acoustic control system can operate at depths of up to 200 feet (61 m). It is also envisaged that the acoustic signal devices (1006, 1008, 1008A) can be probe devices. Other means of acoustic transmission and reception as are known in the art are also provided. It is also envisaged that alternative optical and / or electromagnetic transmission techniques can be used.
The acoustic control system 1007 allows communication through acoustic signaling between the control unit 1004 above the water surface and the subsea control unit 1010. The subsea control unit 1010 can be in electrical communication or in connection with the set of 1012 valves, which can be operable to activate one or more 1015 operational accumulators and release their stored hydraulic fluid. Operational accumulators 1016 can be pre-loaded at 44 Barg (4,400 kPa) although other pressures are also expected. Unlike operating accumulators 1016, one or more receiving or compensating accumulators 1062 may not store pressurized hydraulic fluid for operation of the connection set in the RCD housing 1014, but may, on the contrary, receive the hydraulic fluid exiting the connection set. .
Valve set 1012 can also be used to switch from a primary umbilical line system, such as the second umbilical line 1026 in Figure 13, to the secondary acoustic control system. It is also envisaged that the acoustic control system may be the primary system. The 1016 operational accumulators can be loaded and / or purged remotely or manually, including by an ROV or a diver. Although two 1016 operating accumulators are shown, it is anticipated that there may be only one 1016 operating accumulator, or more than two 1016 operating accumulators.
The operational accumulators 1016 and the receiving accumulator 1064 are arranged with the housing 1014, which can be positioned with an underwater riser or otherwise with the underwater cannon hole, such as with an underwater housing. An RCD or other oil exploration device (not shown in Figure 14) can be connected to the internal connection set on housing 1014. The connection set (not shown) on housing 1014 can be analogous to those connection sets shown in Figures 1 to 12. Frame 1014 can be placed on an underwater riser below the tension lines or the tension ring. Operational accumulators 1016 can provide storage of energized hydraulic fluid to operate the connection set after the signal from the acoustic control system 1007. It is envisaged that bladder type accumulators can be used. Other types of accumulators are also provided, such as the plunger type. Operational accumulators 1015 can be rechargeable in their underwater position.
Using Figure 1 for illustrative purposes, after the acoustic control system and the connection system of Figure 14 are arranged with the system of Figure 1, the operational accumulators 1016 can discharge their fluid in the connection set to move the plunger lower secondary 1000 and / or upper secondary piston 1002, and propel their respective adjacent primary pistons (14, 18) upwards to release their respective retaining elements (16, 20) and disconnect RCD 100 from housing 12 or of the submarine riser 10. It is also envisaged that the accumulators can be used to directly displace the primary pistons (14, 18). It is also envisaged that the accumulators can be used to expand the active seal 22.
Going back to Figure 14, the housing 1014 with the connection set can have a lower flange that can be attached to the subsea riser, subsea housing, wellhead and / or BOP assembly. The internal profile of the housing 1014 may contain a hydraulic connection that is manufactured to receive and release the RCD or other oil exploration device with the locking retainer elements. The housing 1014 may have lifting eyes that lift for convenience in positioning.
Referring to Figure 15, an exemplary configuration for a secondary connection operating system and a primary umbilical line system is shown. The secondary system can be operated using the acoustic control system 1007 in Figure 14. Other modalities and configurations are also provided. Returning to Figure 15, operating accumulators 1016 are shown in communication by hydraulic fluid with the valve assembly 1012. Operating accumulators 1016 may contain hydraulic fluid under pressure as pressurized by nitrogen gas. Although two 1016 operating accumulators are shown, it is also envisaged that only one 1016 operating accumulator can be used. The 1016 operating accumulators can be periodically charged and / or purged. It is anticipated that a pressure gauge can continuously monitor its pressure (s). The meter and / or valves on the charge line can be used to charge and / or purge 1016 accumulators.
Valve set 1012 may include first valve 1040, second valve 1042, and third valve 1044, each of which may be a two-position hydraulic valve. Other types of valves are also provided. The valves (1040, 1042, 1044) can be controlled by a 1078 "pilot" hydraulic line that is pressurized to move the valve. It is also foreseen that a processor or a PLC can control the valves (1040, 1042, 1044) using an electric line. Remote operation is also planned. The assembly The 1012 valve assembly may contain electric over hydraulic valves, pilot operated control valves and manual control valves.
The subsea control unit 1010 (as shown in Figure 14) can mainly direct the operation of the valve set 1012 through commands sent to it from the surface control unit or console 1004. The subsea control unit 1010 can be attached to the same location as a 1064 measuring device or sensor. Other locations for fixing are also provided. It is anticipated that measuring devices or sensors (1064, 1066, 1074, 1046) can measure temperature, pressure, flow and / or other conditions. The sensors (1074, 1076) can be opened for seawater. It is foreseen that the sensors (1064, 1066) can measure the hydraulic pressure and / or the pressure of the sea water, the sensor 1076 can measure the temperature of the sea water and the sensor 1074 can measure the pressure of the sea water. It is also envisaged that other temperatures and pressures, such as pressure in the well, can be measured.
An electro-hydraulic umbilical line, such as the second electro-hydraulic line 1036 shown in Figure 13, comprising three independent hydraulic lines can extend from the drilling platform or structure to the housing with the active connection and / or seal assembly. A first hydraulic line can be attached with the first umbilical inlet port 1046 connected with the first internal umbilical line 1046A, a second hydraulic line can be attached with the second umbilical inlet port 1048 connected with the second internal umbilical line 1048A, and a third hydraulic line can be attached with the third umbilical inlet port 1050 connected with the third internal umbilical line 1050A. The housing with the connection set can be fixed with the first inlet port 1052, the second inlet port 1054 and the third inlet port 1056. The first inlet port 1052 can be in fluid communication with the cavities or space above the (s) primary plunger (s) in the connection set, the second inlet port 1054 may be in fluid communication with the cavities or the space immediately below the primary plunger (s) in the connection set, and the third inlet port 1056 may be in fluid communication with the cavities or the space below the secondary plunger (s) in the connection assembly. Other configurations are also provided for.
Using Figure 1 for illustrative purposes, for the operation of the primary connection set, when permitted by the first valve 1040, the hydraulic fluid from the umbilical line can travel through the first internal umbilical line 1046A through the first inlet port 1052 for the connection set for connecting or closing the connections by displacing the primary pistons (14, 18) down to the positions shown in Figure 1. When allowed by the second valve 1042, the hydraulic fluid from the umbilical line can move through the second internal umbilical line 1048A through the second inlet port 1054 to the connection set to disconnect or open the connections by moving the primary plungers (14, 18) above the positions shown in Figure 1. When allowed by the third valve 1044, the hydraulic fluid from the umbilical line can travel through the third inlet port 1056 p For the connection set to disconnect or open the connections by moving the secondary pistons (1000, 1002) upwards from the positions shown in Figure 1. The operation of the secondary pistons (1000, 1002) is generally used for emergency situations when the primary plungers cannot be displaced.
When the umbilical line is damaged, it may be necessary for the secondary operating system to remove an RCD or other connected oil exploration device. A PLC can control the set of valves 1012 to close the movement of the hydraulic fluid of the first, second and third umbilical lines (1046A, 1048A, 1050A) and the first line for open accumulator 1080, the second line for accumulator 1082 and the third line for accumulator 1083. As can be understood, the first valve, the second valve and the third valve (1040, 1042, 1044) of the valve set 1012 can have a first position and a second position. The first position can allow the operation of the primary system and the second position can allow the operation of the secondary system using the acoustic control system 1007.
The check valves (1068, 1070, 1072) on the hydraulic lines allow flow in the forward direction and prevent flow in the reverse direction. However, it is envisaged that check valves (1068, 1070, 1072) can be pilot-to-open check valves that actually allow flow in the reverse direction when necessary by opening the head. Other types of check valves are also provided. It is also anticipated that there may be no check valve 1072 in the second row for accumulator 1082.
When permitted by valve set 1012, operational accumulators 1016 can discharge their charged hydraulic fluid stored through the third line to accumulator 1083 to move the secondary piston (s), such as the secondary pistons (1000 , 1002) in Figure 1. The hydraulic fluid from the connection set displaced by the movement of the secondary pistons can travel through the first line to accumulator 1080 and / or check valve 1068 to the receiver accumulator or compensator 1062. Other paths are also expected. The receiver accumulator 1062, unlike the operational accumulators 1016, may not contain pressurized hydraulic fluid. On the contrary, it can contain sea water, fresh water or other liquid and can be used to receive or capture the hydraulic fluid that comes back from the connection set to prevent its discharge into the environment or the sea. It is also envisaged that there may be no receiver accumulator 1062, if desired.
It is envisaged that the acoustic control system 1007 can be used as a safety system for the primary system, which may consist of one or more umbilical lines. An electro-hydraulic umbilical drum can be used to store the primary line and supply the RCD frame with electrical and hydraulic power. It is also envisaged that there may also be an access for ROV and / or human diver for system operation. The system is expected to be able to operate at marine depths of up to 197 feet (60 m). The system is expected to operate at temperatures ranging from 32 ° F (0 ° C) to 104 ° F (40 ° C). It is anticipated that the system opening pressure may be 700 (48 bar [4,800 kPa]) or more when conducting a disconnection operation. It is anticipated that the opening pressure system may not exceed 1,200 psi (83 bar [8,300 kPa]) when performing a disconnect operation.
The system's flow rate is not expected to exceed 10 gpm (381 pm) or more when performing a disconnect operation. It is anticipated that the system flow rate may be 0.75 gpm (2.81 bar [281 kPa]) or more to completely disconnect the primary and secondary connections. It is anticipated that the volume of the system flow can be between 0.75 gallons (2.84 liters) and 1.35 gallons (5.11 liters) to disconnect (open) the primary and secondary connection at least once. Operational accumulators 1016 can be recharged in their underwater positions. The system is expected to be operable with the Weatherford Model 7878BTR. As alternative modalities, instead of the 1016 operational accumulators or additionally, a contained energy source can be used, such as an electrical, hydraulic and radio control or other source, so that when remotely signaled it would release the stored energy to make the primary and secondary circuits unlock the connection set to function.
It is anticipated that the fluid will return to the connection set when operating with the acoustic control system and that the system that operates the connections, shown in Figures 14 and 15, would not be ejected into the environment, but will be captured. It is envisaged that the monitoring manometer can be fixed with the charge line of the 1016 operational accumulators, such as the monitoring pressure. The pressure gauge can be used to add or remove hydraulic fluid and to increase or decrease the pressure. There may be valves around the connection and accumulator charge line gauge to allow the system to be loaded or unloaded. The system can be easily fixed with the housing.
Figures 16 to 18 show some of the environments in which the acoustic control system 1007 and the connection operation system of Figures 13-15 can be used. Other environments are also planned. In Figure 16, the floating drilling platform or structure S is arranged on the wellhead W. The BOPS subsea BOP assembly is disposed on the wellhead W and the subsea riser R with the annular BOP GH manipulator extends between the BOPS and platform S. The tension lines T are fixed with the slide joint SJ near the top of the riser R with a tension ring (not shown). A diverter D is located under the floor of platform F.
The acoustic control system 1007 is positioned with the S structure and with the R riser. An RCD or other oil exploration device (not shown) can be connected inside the housing 1014 positioned with the riser R below the tension lines T and the tension ring adjacent to the GOP gas manipulator annular BOP site. It is envisaged that a 1014 housing with connected RCD or other connected oil exploration device may be arranged with a frame or pod structure supporting the set of valves 1012, accumulators (1016, 1062), the subsea control unit 1010, and the devices subsea signals (1008, 1008A). Surface equipment including surface control unit 1004, drum 1005, and signal device 1006 can receive support from platform S.
In Figure 17, the RCD 38A is arranged with an underwater SH shell on the SF seabed and disposed with the underwater wellhead W. The SH underwater housing and the RCD 38A allow underwater drilling without any underwater riser. In Figure 18, RCD 38a is arranged with the SH1 submarine housing on the BOPS submarine BOP set. The SH1 underwater housing and the RCD 38A allow underwater drilling without any underwater risers. The acoustic control system 1007 and the connection operation system as shown in Figures 13-16 can be arranged with the undersea housings (SH, SH1) of Figures 17 and 18 and used to operate the connection set for connecting and disconnecting the RCD 28A and / or for the expansion and reduction of an active seal. It is envisaged that the system components can be supported on the frame or pod structure.
With reference to Figure 19, an RCD 1102 is connected to the 1100 housing. Although an RCD 1102 is shown, it is envisaged that any oil exploration device can be connected to the 1100 housing. Although during operation, the housing 110 would be arranged below from the sea with a submarine riser or directly with the wellhead or BOP set, if there is no riser. Frame 1100 has an internal connection set for connecting RCD 1102 or another oil exploration device. The accumulators (1106, 1108) are removably attached to the housing 1100 with the accumulator compression ring 1104. There can be four accumulators, such as those shown in Figure 21. As discussed above, other numbers of accumulators are contemplated. Referring again to Figure 19, signal device 1110 is in a retracted position below the accumulators (1106, 1108). The accumulators can store a fluid for the operation of the internal connection assembly of the housing 1100. In Figure 20, the signal device 1110 has been moved to an operational position.
In Figure 21, three operational accumulators (1106, 1108, 1112) are provided for the release of the hydraulic fluid to the connection set, as discussed above, in frame 1100. A receiving or compensating accumulator 1114 is intended to receive hydraulic fluid from the set connection points on housing 1100. The accumulators (1106, 1108, 1112, 1114) are attached to the housing 1100 using the accumulator compression ring 1104. As shown in Figure 22, the signal device (1110, 1110A) is displaceable by articulating a retracted position (in dashed view) to an operational position.
Referring to Figures 23A-23B, an exemplary configuration for a secondary connection operating system and a primary umbilical line system is shown. The secondary system can be operated with the acoustic control system 1007. Other modalities and configurations are also provided. The operational accumulators (1120, 1122, 1124) are shown in communication by hydraulic fluid with the distributor or with the 1128 valve set. The operational accumulators (1120, 1122, 1124) can contain hydraulic fluid under pressure, pressurized by nitrogen gas. Although three operational accumulators are shown in Figures 21-23A, it is also anticipated that only one operational accumulator could be used. Operational accumulators can be periodically charged and / or purged. A pressure gauge is expected to continuously monitor your pressure (s). The pressure gauge and / or valves on the charge line can be used to charge and / or bleed accumulators. The accumulator or compensator 1126 can be used to receive hydraulic fluid as described above.
The distributor or set of valves 1128 may include first valve 1130, second valve 1132 and third valve 1134, each of which may be a two-position hydraulic valve. Other types of valves are also provided. The valves (1130, 1132, 1134) can be controlled by a "pilot" hydraulic line 1136 which is pressurized to move the respective valve. As best seen in Figure 23B, the acoustic control system 1007 can use an electrical control through the hydraulic through valves (1130, 1132, 1134). The valves (1160, 1162, 1164) control the function of both switching from the primary umbilical line system to the secondary connection operation system and performing the emergency disconnection operation by the secondary connection operation system. The valves (1160, 1162) can be electrically controlled by the subsea control units (SCU) (1136, 1138) as shown in Figure 23A. The 1164 valve is operated by the 1162 pilot operated control valve.
More specifically, the activation of valve 1164 will operate by pilot and switch valves (1130, 1132, 1134) from the primary umbilical line system to the secondary connection operation system. This switching allows the connection set where the 1164 valve is activated by the 1162 pilot operated control valve to be disconnected in the emergency. Activation of the 1164 valve allows the pressurized hydraulic fluid from the accumulator (s) (1120, 1122, 1124) disconnect the RCD or other oil exploration device from the housing using the secondary connection operation system.
The accumulators (1120, 1122, 1124) can be 10-liter underwater bladder accumulators with a sealing subfluid connection, a 1/4 "BSD gas connection, a C / W lifting eye bolt, a SCHRADER valve and a damping ring. The 1126 compensator can be a 10 liter submarine compensator, being a 1/4 "BSP connection for hydraulic fluid that is internally coated with nickel, open connection for sea water with a projected pressure of 207 BARG and damping ring C / W. A 1166 valve can be a 3/8 "C / W 1/2" OD x 0.65 "W NB submarine manual needle valve 38 mm floating tube. Coupler 168 can be unventilated universal single coupler C / W mounted on a 3/8 "NB male flange with a 1000 mm 1/2" x 0.05 "WT floating tube. The 1170 coupler can be a non-ventilated C / W universal mono coupler mounted on 3/8 "NB female flange with JIC CHEMRAS # 8 seals. The 1172 couplings can consist of a C / W hydraulic universal coupling mounted on the female insert plate 1/4 "NB non-vented, 17 mm holes UNC 1/4" rear end under seal. 1174 couplings can consist of "reduced force" hydraulic universal couplings mounted on 1/4 "NB male insert plate , not ventilated # 8 JIC. Valves 1130, 1132, and 1134 can consist of a normally open, 2-position, 3-way head valve. The 1164 valve can be a 2-position, two-way, normally closed, head valve. The 1160 and 1162 valves can be a 2-position, 3-way 24-volt DC C / W solenoid valve normally closed 3m from RAYCHEM floating connectors. The 1146 sensor can be a 1/4 "BSP pressure transducer mounted on the distributor, 0-1000 BARG. The 1144 transducer can be a 1/4" BSP temperature transducer mounted on the distributor (seawater temperature). Holes 1154, 1156 and 1158 could include male coupling of a 1/4 ", 569 BARG 11/2" x 0, 065 "WT x 1000 mm float tube. A processor or PLC is also provided could control the valves (1130, 1132, 1134) using an electric line. Remote operation is also provided. The 1128 valve set can contain electric valves via hydraulics, pilot operated control valves, and / or manual control valves .
The subsea control units (1136, 1138) can mainly direct the operation of the 1128 valve assembly through commands sent to the subsea control units of a surface control unit or console, such as the 1004 unit shown in Figures 14 and 16 The subsea control units (1136, 1138) can be attached in the same location as the measuring device or sensor 1140. Other locations for attachment are also provided. Measuring devices or sensors (1140, 1142, 1144, 1146) can measure temperature, pressure, flow and / or other conditions. The sensors (1144, 1146) can be open to sea water. It is foreseen that the sensors (1140, 1142) can measure the hydraulic pressure or the pressure of the sea water, the sensor 1146 can measure the temperature of the sea water and the sensor 1144 can measure the pressure of the sea water. It is anticipated that other temperatures and pressures can be measured, such as pressure in the well.
An electro-hydraulic umbilical line such as the second electro-hydraulic line 1026, shown in Figure 13, containing three independent hydraulic lines can extend from the drilling platform or structure to the housing with an active connection or seal assembly. With reference to both Figure 23A and 23B, a first hydraulic line can be attached with the first umbilical inlet port 1148 connected with the first internal umbilical line 1148A, a second hydraulic line can be connected with the second umbilical inlet port 1150, connected with the second internal umbilical line 1150A, and a third hydraulic line can be connected with the third umbilical inlet port 1152 connected with the third internal umbilical line 1152A. The housing with the connection set can be connected with the first inlet 1154, with the second inlet 1156, with the third inlet 1158. The first inlet 1154 can be in fluid communication with the cavities or space above the primary pistons in the connection set, the second inlet port 1156 may be in fluid communication with the cavities or space immediately below the primary pistons in the connection set, and the third inlet port 1158 may be in communication by fluid with the cavities or space below the secondary pistons in the connection set. Other configurations are also provided for.
As will now be understood, the system can monitor the temperature and pressure of seawater and the stored hydraulic supply and return pressure. The system also provides the ability to remotely control open and closed valves and provides sufficient volume stored in the accumulators to operate the emergency disconnect in the event of a primary and secondary hydraulic failure. The design of the control system can be based on two underwater acoustic control units (SCUs) mounted on the housing that will receive signals from the surface acoustic control unit and operate the directional control valves. The two subsea acoustic control units will also send signals, such as 4-20 mA signals, to the surface acoustic control unit. As best seen in Figure 23A, two subsea acoustic control units (SCUs) (1136, 1138) can be used, but it should be understood that only one SCU can be used to implement the function of the acoustic control system to implement the function of the 1008 acoustic control system. The system design can offer, among other things, (1) a redundant subsea system with two complete sets of electronic components with separate replaceable batteries, (2) high availability and reliability based on selection equipment, design principles (3) low electricity consumption and (4) low maintenance. It is expected that:
- the system can operate in seawater up to 197 feet (60 meters) below the surface the system can operate within 32 ° F (0 ° C) and 104 ° F (40 ° C) temperature limits - system opening pressure can be 700 psi (48 bar [4,800 kPa]) or more when performing an emergency shutdown (opening) operation - the opening pressure of the system cannot exceed 1200 psi (83 bar [8,300 kPa]) when performing an emergency disconnection (opening) operation - the system flow rate must not exceed 0.75 gpm (2.84 liters per minute) when an emergency disconnect (opening) operation is performed - the flow rate of the system cannot exceed 0.75 gallons (2.84 liters) and 1.35 gallons (5.11 liters) to fully disconnect (open) the primary and secondary connecting pistons.
However, other values or ranges of values can be applied to other modalities.
Although the invention has been described in terms of preferred embodiments as presented above, it should be understood that these embodiments are illustrative only and that the claims are not limited to those embodiments. Those skilled in the art will be able to make modifications and introduce alternatives taking into account the invention, these modifications and alternatives being considered to fall within the scope of the appended claims. Each feature described or illustrated in this report can be incorporated into the invention, either individually or in any suitable combination with any other feature described illustrated in this document.

权利要求:
Claims (33)
[0001]
System for the operation of a connection set (210 ') used with an oil exploration device, CHARACTERIZED by the fact that it comprises:
the connection set (210 ') arranged in a housing (1020) configured to be positioned below a water surface;
a first signal device (1006) configured to be disposed below the water surface; and
a second signal device (1008) coupled to the housing (1020), wherein the connection set (210 ') is configured to operate in response to a first signal transmitted wirelessly and remotely from the first signal device (1060) via a body of water to the second signal device (1008) when the first signal device (1060) is spaced from and is not connected with the housing (1020);
a first accumulator (1023) configured to communicate with the connection set (210 ');
an umbilical line (1026) configured to communicate with the connection set (210 '); and
a first valve (1040) configured to control fluid communication with the connection set (210 ') of the umbilical line (1026) or the first accumulator (1023).
[0002]
System, according to claim 1, CHARACTERIZED by the fact that it also comprises:
a first control unit (1004) connected to the first signal device (1006), and
a second control unit (1010) connected to the second signal device (1008) and configured to be coupled to the housing (1020), the second signal device (1008) being configured to receive the first signal from the first signal device (1006) ) to move the connection set (210 ') in response to the first signal.
[0003]
System, according to claim 2, CHARACTERIZED by the fact that it also comprises:
the first accumulator (1023) configured to contain a hydraulic fluid in fluid communication with the connection set (210 '), and coupled to the housing (1020);
wherein the hydraulic fluid from the first accumulator communicated to the connection assembly (210 ') in response to the first signal from the first signal device (1006).
[0004]
System according to claim 1, CHARACTERIZED by the fact that the first signal device (1006) is a transmitter and the second signal device (1008) is a receiver.
[0005]
System according to claim 2, CHARACTERIZED by the fact that the first signal device (1006) and the second signal device (1008) are operable to transmit and receive signals allowing a two-way wireless communication connection between the first control unit (1006) and the second control unit (1008).
[0006]
System, according to claim 3, CHARACTERIZED by the fact that it also comprises:
the umbilical line (1026) configured to communicate a hydraulic fluid to operate the set of
connection (210 '); and
the first valve (1040) in fluid communication with the connection set (210 ') having a first position that allows the flow of hydraulic fluid from the umbilical line to the connection set (210'), and a second position that allows the flow of the hydraulic fluid from the first accumulator to the connection set (210 ').
[0007]
System, according to claim 3, CHARACTERIZED by the fact that it also comprises:
a primary piston (220 ') in the connection set (210') in communication with the first accumulator (1023) for the communication of the hydraulic fluid of the first accumulator.
[0008]
Method for the operation of a connection set (210 ') used with an oil exploration device connectable with a housing (1020), CHARACTERIZED by the fact that it comprises:
coupling a second signal device (1008) together with the housing (1020);
the displacement of the second signal device (1008) under a water surface,
moving a first signal device (1006) under the surface of the water without connecting the first signal device (1006) to the housing (1020), where the first signal device (1006) is spaced from the housing (1020) ;
after the displacement steps, the transmission of a first signal wirelessly and remotely between the first signal device (1006) and the second signal device (1008) through a body of water;
controlling a valve (1040) configured to communicate the connection assembly (210 ') with a first fluid source or a second fluid source; and
the displacement of a plunger (220 ') in the connection assembly (210') in response to the first signal.
[0009]
Method, according to claim 8, CHARACTERIZED by the fact that it also comprises the step of:
disconnection of the oil exploration device from the housing (1020) after the piston displacement step, or
connection of the oil exploration device with the housing (1020) after the piston displacement step.
[0010]
Method, according to claim 8, CHARACTERIZED by the fact that the first source of fluid is a first accumulator (1023) and the control step further comprises:
the communication of hydraulic fluid from the first accumulator (1023) in response to the first signal, the communicated hydraulic fluid displacing the plunger within the connection assembly (210 ').
[0011]
Method according to claim 8, or system according to claim 1, CHARACTERIZED by the fact that the housing (1020) is arranged with, or is configured to be arranged with, a submarine riser.
[0012]
Method according to claim 8, or system according to claim 4, CHARACTERIZED by the fact that the first signal device (1006) and the second signal device (1008) comprise transceivers, preferably for transmission and transmission. receiving the first signal.
[0013]
Method according to claim 8, CHARACTERIZED by the fact that it further comprises the step of: communicating hydraulic fluid from the connection set (210 ') to a second accumulator.
[0014]
Method, according to claim 10, CHARACTERIZED by the fact that the second fluid source is an umbilical line (1026) and the control step also comprises the steps of:
allow a flow of hydraulic fluid from the umbilical line (1026) to the connection set (210 ');
block a flow of hydraulic fluid from the umbilical line (1026) to the connection assembly (210 '), and
allow the flow of hydraulic fluid from the first accumulator (1023) to the connection set (210 ').
[0015]
Method according to claim 8, or system according to claim 7, CHARACTERIZED by the fact that it further comprises a secondary piston in the connection set (210 '), preferably in communication with the first accumulator (1023) for the communication of the hydraulic fluid of the first accumulator.
[0016]
Method, according to claim 8, CHARACTERIZED by the fact that it also comprises the step of:
before the transmission step, articulate the second signal device (1008) from a retracted position coupled with the housing (1020) to an operational position coupled with the housing (1020).
[0017]
System for the operation of a connection set (210 ') used with an oil exploration device, CHARACTERIZED by the fact that it comprises:
a housing (1020);
a valve (1040) coupled with the housing (1020) and in fluid communication with the connection set (210 ');
an umbilical line (1026) configured to communicate a fluid and in fluid communication with the valve (1040); and
a first accumulator (1023) configured to contain a fluid and in fluid communication with the valve (1040), the valve (1040) being configured to be displaceable between a first position, to allow a flow of the hydraulic fluid from the umbilical line to operate the connection set (210 '), and a second position, to allow a flow of hydraulic fluid from the first accumulator to operate the connection set (210').
[0018]
System, according to claim 17, CHARACTERIZED by the fact that it also comprises:
a first signal device (1006) for transmitting a signal; and
a second signal device (1008) coupled with the housing (1020) to receive the signal from the first signal device (1006) when the first signal device (1006) is spaced from and is not connected with the housing (1020);
the first accumulator (1023) being configured to allow a flow of hydraulic fluid from the first accumulator to the connection assembly (210 ') in response to a first signal transmitted via a wireless communication link of the first signal device (1006 ) to the second signal device (1008).
[0019]
System according to claim 18, CHARACTERIZED by the fact that the first signal device (1006) is configured to transmit and receive signals from the second signal device (1008) in a body of water, and the second signal device ( 1008) is configured to transmit and receive signals from the first signal device (1006) in a body of water.
[0020]
System according to claim 1 or 18, or method according to claim 8, CHARACTERIZED by the fact that the first signal is an acoustic signal.
[0021]
System, according to claim 18, CHARACTERIZED by the fact that it also comprises:
a first control unit configured to be arranged above a body of water; and
a second control unit configured to be disposed within the water body,
the first control unit being configured to control the first signal device (1006) to transmit the first wireless signal through the body of water to the second control unit.
[0022]
System, according to claim 17, CHARACTERIZED by the fact that it also comprises:
a second accumulator configured to be in fluid communication with the connection set (210 ') to receive a fluid from the connection set (210').
[0023]
Apparatus for connecting an oil exploration device, CHARACTERIZED by the fact that it comprises:
a housing (1020) having a connection assembly (210 ');
a valve (1040) coupled to the housing (1020);
a first accumulator (1023) coupled to the housing (1020) and configured to communicate a fluid from the first accumulator (1023) to the connection assembly (210 '); and
a first signal device (1006); and
a second signal device (1008) coupled
with the housing (1020) and configured to receive a signal
wireless signal device (1006) when the
first signal device (1006) is spaced from and not
it is connected with the housing (1020) to move the valve (1040) from a locking position to an open position to allow the flow of hydraulic fluid from the first accumulator to the connection assembly (210 ').
[0024]
Apparatus, according to claim 23, CHARACTERIZED by the fact that it further comprises:
an insertion plate attached to the housing (1020); and
a coupling plate, the insertion plate and the coupling plate allowing the releasable coupling of the first accumulator (1023) and the second signal device (1008) with the housing (1020).
[0025]
Apparatus, according to claim 23, CHARACTERIZED by the fact that it further comprises:
an accumulator compression ring for mounting the first accumulator (1023) and the second signal device (1008), and
a lifting element configured to lift the accumulator compression ring.
[0026]
Apparatus according to claim 23, CHARACTERIZED by the fact that the first accumulator (1023) and the second signal device (1008) are releasably coupled to the housing (1020).
[0027]
Apparatus according to claim 23, CHARACTERIZED by the fact that the first accumulator (1023), the second signal device (1008) and the control unit are releasably coupled to the housing (1020).
[0028]
Apparatus for use with an oil exploration device, CHARACTERIZED by the fact that it comprises:
an active seal;
a housing (1020) for receiving the active seal;
a valve (1040) coupled to the housing (1020);
a first accumulator (1023) coupled with the housing (1020) and configured to communicate a fluid from the first accumulator (1023) to the active seal;
a first signal device (1006); and
a second signal device (1008) coupled to the housing (1020) and configured to receive a wireless signal from the first signal device (1006) when the first signal device (1006) is spaced from and is not connected with the housing ( 1020) to move the valve (1040) from a locking position to an open position to allow the hydraulic fluid to flow from the first accumulator to the active seal.
[0029]
Apparatus according to claim 23 or 28, CHARACTERIZED by the fact that it further comprises:
a control unit coupled to the housing (1020) and configured to receive the signal from the second signal device (1008) to move the valve (1040).
[0030]
Apparatus according to claim 23 or 28, or system according to claim 3, CHARACTERIZED by the fact that it further comprises:
a second accumulator coupled with the housing (1020) and configured to receive a hydraulic fluid from the active seal or connection set (210 ').
[0031]
Apparatus according to claim 23 or 28, CHARACTERIZED by the fact that the signal device comprises a first transducer and a transducer.
[0032]
Apparatus, according to claim 31, CHARACTERIZED by the fact that the first transducer is movably coupled in relation to the housing (1020), the first transducer being displaceable between a retracted position and an operational position.
[0033]
Apparatus according to claim 23 or 28, CHARACTERIZED by the fact that the oil exploration device is a rotary control device having a bearing between an internal element that can rotate in relation to an external element.

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同族专利:

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公开号 | 公开日

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CA2815101A1|2012-04-26|

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EP3636875A1|2020-04-15|

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BR112013009489A2|2016-07-26|

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AU2011317657A1|2013-05-09|

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US20160245037A1|2016-08-25|

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US9359853B2|2016-06-07|

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US20120000664A1|2012-01-05|

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EP2630324B1|2019-09-18|

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AU2011317657B2|2016-11-03|

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CA2815101C|2018-08-28|

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WO2012052402A3|2013-06-27|

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EP2630324A2|2013-08-28|

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WO2012052402A2|2012-04-26|

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AU2016273935A1|2017-01-12|

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法律状态:
2018-03-13| B25A| Requested transfer of rights approved|Owner name: WEATHERFORD TECHNOLOGY HOLDINGS LLC (US) |

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2018-10-02| B25D| Requested change of name of applicant approved|Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC (US) |

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2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|

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2019-08-20| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|

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2020-04-14| B09A| Decision: intention to grant|

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2020-06-23| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 17/10/2011, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

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申请号 | 申请日 | 专利标题

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US39415510P| true| 2010-10-18|2010-10-18|

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US61/394,155|2010-10-18|

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US13/233,846|US9359853B2|2009-01-15|2011-09-15|Acoustically controlled subsea latching and sealing system and method for an oilfield device|

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US13/233,846|2011-09-15|

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PCT/EP2011/068111|WO2012052402A2|2010-10-18|2011-10-17|Latching apparatus and method|

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