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    • 专利摘要:
    BLADE SET OF A WELL SHUTTER BLOCK AND METHOD FOR SHARING A TUBULAR FROM A WELL HOLE. Techniques are described here that relate to a set. blade of a well plug block to shear a tubular from a well hole that penetrates an underground formation. The well plug block has a housing with a hole through it to receive the tubular. The blade assembly includes a movable piston block between a non-engaging position and an engaging position around the tubular, a blade carried by the piston block and movable sliding along it, and a release mechanism to selectively release the guide to move between a guide position, to guide the engagement with the tubular, and a cutting position at a distance behind the blade to allow the blade to engage sharply the tubular.
    公开号:BR112013007713B1
    申请号:R112013007713-1
    申请日:2011-09-29
    公开日:2020-11-24
    发明作者:Frank Benjamin Springett；Christopher Dale Johnson；Shern Eugene Peters；Eric Trevor Ensley
    申请人:National Oilwell Varco, L.P；
    IPC主号:
    专利说明:

    Fundamentals of the Invention 1. Field of the Invention
    [0001] The present invention relates in general to techniques for performing operations at the well site. More specifically, the present invention relates to techniques, such as a tubular centering device and / or a well plug (BOP) block. 2. Description of the Related Art
    [0002] Oil field operations are typically performed to locate and collect valuable deep-hole fluid. Oil platforms can be positioned on drilling sites and deep hole tools, such as drilling tools, can be deployed on the ground to reach subsurface reservoirs. Once the deep hole tools form a well hole to reach a desired reservoir, coatings can be cemented into place in the well hole, and the well hole completed to start producing fluid from the reservoir. Tubular or tubular columns can be positioned in the well bore to allow the passage of subsurface fluids from the reservoir to the surface.
    [0003] Leaking subsurface fluids can present an environmental risk if released by the well bore. Equipment, such as BOPs, can be positioned around the borehole to form a seal around a tubular in it, for example, to prevent leakage of fluid as it is brought to the surface. BOPs may have selectively actuable pistons or piston flaps, such as tubular pistons (for contacting, engaging and / or enclosing tubulars to seal the well bore) or shear pistons (for making contact and physically shearing a tubular), which can be activated to split and / or seal a tubular in a borehole. Some examples of piston BOPs and / or piston blocks are provided in patent / patent application Nos. 3,554,278, 4,647,002, 5,025,708, 7,051,989, 5,575,452, 6,374,925, 7,798,466, 5,735,502, 5,897,094 and 2009/0056132. Techniques have also been provided for cutting pipe in a BOP disclosed, for example, in U.S. Patent Nos. 3,946,806, 4,043,389, 4,313,496, 4,132,267, 2,752,119, 3,272,222, 3,744,749, 4,523,639, 5,056,418, 5,918,851, 5,360,061, 4,923,005, 4,537. 250, 5,515,916, 6,173,770, 3,863,667, 6,158,505, 4,057,887, 5,505,426, 3,955,622, 7,234,530 and 5,013,005. Some BOPs can be provided with guides as described, for example, in U.S. patents 5,400,857. 7,243,713 and 7,464,765.
    [0004] Despite the development of techniques for tubular cutting, there remains a need to provide advanced techniques to more effectively seal and / or split tubulars. The present invention aims to fill this need in the art. Summary of the Invention
    [0005] In at least one aspect, the object matter may relate to a blade assembly of a well plug block to shear a tubular from a well hole that penetrates an underground formation, the well plug having a housing with a hole through it to receive the tubular. The blade assembly includes a movable piston block between a non-engaging position and an engaging position around the tubular, a blade loaded by the piston block to engage the tubularly cut, a retractable guide loaded by the piston block and slidably movable along it, and a release mechanism to selectively release the guide to move between a guide position to guide the engagement with the tubular and a cut position at a distance behind the blade to allow the blade to engage cutting or tubular.
    [0006] The release mechanism can be activated by applying a disconnecting force to its guide surface. The blade assembly may also include a trigger to activate the release mechanism. The trigger may include a plunger operably connectable to the release mechanism. The plunger can be positioned around an apex of the guide and / or along a guide guide surface. The plunger can include a plurality of contacts. Each of the contacts can be operationally coupled to an element by a rod. The element can be slidably positioned on a guide channel trigger. The plunger may have at least one trigger guide slidably positioned in at least one trigger slot in the guide.
    [0007] The release mechanism may include an element operatively coupled to the trigger and slidably positioned in a trigger channel of the guide. The release mechanism may also include a plurality of request elements for supporting the element in the guide channel, a plurality of wedges selectively movable between a locked position and an unlocked position on the guide by the movement of the element, and / or a plurality of loaded projections wedges and selectively movable along a plurality of passages in the guide. The passages can be in fluid communication with tubes extending through the guide for the passage of fluid through them. The release mechanism may include a positionable ferrule adjacent to an edge of the piston block. The piston block can have a ramp for sliding the ferrule.
    [0008] The guide may include a plurality of springs and the release mechanism may include a plurality of latches which can be releasably connected to the plurality of springs. The latches can be pivotable on the piston block to selectively engage the plurality of springs.
    [0009] The piston blocks can have guide pins that can be received by the guide slots in the guide for sliding movement along them. The piston blocks may have shoulders for sliding engagement with the guide. The guide surface may be concave with an apex along its central axis. The guide surface may have a first portion at a first angle with the central axis and / or a second portion at a second angle to the central axis.
    [00010] In another aspect, the object matter may refer to a well block to shear a tubular from a well hole that penetrates an underground formation. The well plug block may include a housing with a hole through it to receive the tubular and a pair of blade assemblies. Each of the blade assemblies may include a movable piston block between a non-engaging position and an engaging position around the tubular, a blade carried by the piston block to cut the tubularly, a retractable guide carried by the block piston and slidably movable along it, and a release mechanism to selectively release the guide to move between a guide position to guide the engagement with the tubular and a cut position at a distance behind the blade to allow the blade engage sharply or tubularly.
    [00011] The retractable guide may have a cavity for receiving a tip from another retractable guide positioned opposite it. The well plug block may also include at least one actuator to actuate the piston block for each of the blade assemblies. The release mechanism may include a trigger for its activation. The trigger can be activated by contact with the tubular and / or by contact with another guide.
    [00012] Finally, in another aspect, the object matter may concern a method for shearing a tubular from a well hole that penetrates an underground formation. The method may involve providing a well plug including a housing with a hole through it to receive the tubular and a pair of blade assemblies. Each of the blade assemblies may include a piston block, a blade carried by the piston block, a retractable guide carried by the piston block, and a release mechanism. The method may additionally involve moving the piston block between a non-engaging position and an engaging position around the tubular, selectively releasing the release mechanism, slidingly moving the guide between a guide position to guide the engagement with the tubular and a cutting position at a distance behind the blade to allow the blade to engage the tubularly cutting, and to engage the tubularly cutting with the blade.
    [00013] Selective release can occur by applying a disconnecting force. Selective release may include moving a ferrule along a piston block ramp, unlocking the guide, triggering the release mechanism, and / or moving the release mechanism between a locked and an unlocked position. The method may additionally involve guiding the tubular to a desired position on the well plug block with the guide.
    [00014] In certain aspects of the present invention, a well plug block is provided comprising: a guide, mounted on a piston block, to guide a tubular towards a cutting and / or shear position within the well plug block. ; a mechanism positioned to detect when said tubular has reached said cut and / or shear position; and a blade to cut / shear the tubular; the arrangement being such that, in use, said blade is operable only to cut / shear said tubular when said mechanism detects said tubular in said cut and / or shear position. In some embodiments, the guide may remain in contact with the tubular while the blade cuts / shears the tubular. In other embodiments, the guide can retract out of contact with the tubular either just before or shortly after the blade comes in contact with the tubular. Either way, there may be a pulling and / or disconnecting force that the piston block has to overcome as the guide is pushed against the tubular before the blade can cut / shear the tubular. Brief Description of Drawings
    [00015] In order that the aforementioned resources and advantages of the present disclosure can be understood in detail, a more particular description of the disclosure, previously summarized, can be taken by reference to its modalities that are illustrated in the attached drawings. however, that the attached drawings illustrate only typical modalities and, therefore, should not be considered limiting its scope, since the disclosure may admit other equally effective modalities.The figures are not necessarily in scale and certain features and certain views of the figures they may be shown in an exaggerated scale or schematically for clarity and conciseness.
    [00016] Figure 1 is a schematic view of an offshore well location with a well plug (BOP) block with a blade assembly.
    [00017] Figure 2 is a schematic view, partially in cross-section, of the BOP in figure 1 before starting a BOP operation.
    [00018] Figure 3-6 are several schematic views of a portion of the blade assembly of figure 1 with a blade and a tubular centering system.
    [00019] Figures 7-17 are schematic views of a portion of a cross section of BOP 104 in figure 2 taken along line 7-7 and representing the blade assembly dividing a tubular.
    [00020] Figures 18-22 are schematic top views of various blade assemblies with latch release mechanisms.
    [00021] Figures 23-24 are schematic top views of various blade assemblies with trigger activated release mechanisms.
    [00022] Figures 25A-25B are schematic top views of a blade assembly with a trigger activated wedge release mechanism.
    [00023] Figures 26A-26B are schematic top views of a blade assembly with a trigger activated multicontact wedge release mechanism.
    [00024] Figures 27A-27B are schematic top views of a blade assembly with a trigger activated multi-contact wedge release mechanism.
    [00025] Figure 28 is a flow chart representing a method for shearing a tubular from a well hole. Detailed Description of the Invention
    [00026] The description that follows includes exemplary instructional sequences that incorporate techniques of the present subject matter. However, it must be understood that the modalities described can be practiced without these specific details.
    [00027] The techniques here concern blade assemblies for well plug blocks. These blade sets are configured to provide tubular centering and shearing capabilities. Retractable guides and / or release mechanisms can be used to position the tubulars during shear. It may be desirable to provide techniques for positioning the tubular before dividing the tubular. It may be additionally desirable for such techniques to be performed on tubular of any size, such as those with a diameter of up to about 8 "(21.59 cm) or more. Such techniques may involve one or more of the following, among others: tubular positioning, efficient exchange of parts, low blade wear, less force required to divide the tubular, efficient division, and less maintenance time for part replacement.
    [00028] Figure 1 represents a well location off the coast 100 with a blade assembly 102 in a housing 105 of a well plug block (BOP) 104. Blade assembly 102 can be configured to centralize a tubular 106 in the BOP 104 before or simultaneously with a division of tubular 106. Tubular 106 can be fed through BOP 104 and into a well bore 108 that penetrates an underground formation. The BOP 104 can be part of an underwater system 110 positioned on a floor 112 of the sea. Submarine system 110 may also comprise tubular (or tube) 106 extending from well bore 108, a well head 114 around well bore 108, a conduit 116 extending from well bore 108 and other subsea devices, such as a sowing paddle and a transport dispensing system (not shown).
    [00029] Blade assembly 102 can have at least one tubular centering system 118 and at least one 120 blade. Tubing centering system 118 can be configured to center tubular 106 within BOP 104 before and / or simultaneously with the engagement of the blade 120 with the tubular 106, as will be discussed in more detail below. The tubular centering system 118 can be coupled to the blade 120, or move with it, thereby allowing the centering of tubular 106 without using extra actuators, or the need to machine the body of the BOP 104.
    [00030] Although the well location off the coast 100 is represented as a subsea operation, it is realized that the well location 100 can be based on land or water, and blade set 102 can be used anywhere in the well environment. Tubular 106 can be any tubular and / or transfer suitable for running tools in well hole 108, such as certain deep-hole tools, pipe, liner, drill pipe, inner liner, coiled tubing, production tubing, power cable conventional profiling, thin non-metallic cable, or other tubular elements positioned in the well bore and associated components, such as drilling collars, tool joints, drill bits, profiling tools, shutters, and the like (referred to here as "tubular" or "tubular columns").
    [00031] A surface system 122 can be used to facilitate operations at the well site off the coast 100. The surface system 122 can comprise a drilling platform 124, a platform 126 (or vessel) and a surface controller 128. In addition, there may be one or more subsea controllers 130. Although surface controller 128 is shown as part of surface system 122 at a location on the surface, and subsea controller 130 is shown as part of subsea system 110 at a subsea location, it is realized that one or more surface controllers 128 and subsea controllers 130 can be located in various locations to control the surface and / or subsea systems.
    [00032] To operate the blade assembly 102 and / or other devices associated with the location of the well 100, the surface controller 128 and / or the subsea controller 130 can be placed in communication with it. The surface controller 128, the subsea controller 130, and / or any device at the well location 100 can communicate via one or more communication links 132. The communication links 132 can be any suitable communication system and / or device, such as such as hydraulic lines, pneumatic lines, wiring, optical fibers, telemetry, acoustics, wireless communication, any combination of these, and the like. Blade assembly 102, BOP 104, and / or other devices at the well 100 site can be operated automatically, manually and / or selectively via surface controller 128 and / or subsea controller 130.
    [00033] Figure 2 shows a schematic cross-sectional view of the BOP 104 of figure 1 with the blade assembly 102 and a seal assembly 200. The BOP 104, as shown, has a hole 202 through a central axis 204 of the BOP 104. Hole 202 may be for receiving tubular 106. BOP 104 may have one or more channels 206 for receiving blade assembly 102 and / or seal assembly 200. As shown, there are two channels 206, one with the assembly blade 102 and the other with seal assembly 200 on it. Although there are two channels 206, it should be noted that there can be any number of channels 206 housing any number of blade assemblies 102 and / or seal assemblies 200. Channels 206 can be configured to guide blade assembly 102 and / or the seal assembly 200 radially in favor and against the tubular 106.
    [00034] BOP 104 can allow tubular 106 to pass through BOP 104 during normal operation, such as inward operation, drilling, profiling and the like. In the event of a breakdown, pressure surge, or triggering event, BOP 104 can split tubular 106 and / or seal hole 202 to prevent fluids from being released through well hole 108. Although BOP 104 is represented with a specific configuration, it is realized that the BOP 104 can have a variety of shapes, and be provided with other devices, such as sensors (not shown). An example of a BOP that can be used is described in U.S. patent no. 5,735,502, whose contents in full are hereby incorporated by reference.
    [00035] Blade assembly 102 can have tubular centering system 118 and blades 120 each attached to a piston block 208. Each of the piston blocks 208 can be configured to contain (and load) the blade 120 and / or the tubular centering system 118 as blade 120 moves within BOP 104. Piston blocks 208 can engage actuators 210 via piston shafts 212 in order to move blade assembly 102 within the channel 206. Actuator 210 can be configured to move piston shaft 212 and piston blocks 208 between an operating (or non-engaging) position, as shown in figure 2, and an actuated (or engaging) position in which piston blocks 208 engaged and / or divided tubular 106 and / or sealed hole 202. Actuator 210 can be any suitable actuator, such as a hydraulic actuator, a pneumatic actuator, a servo, and the like. The seal assembly 200 can also be used to center the tubular 106 in addition, or alternatively, to the tubular centering system 118.
    [00036] Figure 3 is a schematic perspective view of a portion of the blade assembly 102 with the blade 120 and the tubular centering system 118. The blade 120 and the tubular centering system 118 are supported by one of the piston blocks 208. It should be noted that there may be another piston block 208 retaining another of the blades 120 and / or the tubular centering systems 118 working in cooperation with it, as shown in figure 2. Blade 120, as shown, it is configured to split tubular 106 using multiphase shear. The blade 120 may have a drilling tip 300 and one or more valleys 302 along an engaging end of the blade. In addition, any blade suitable for dividing the tubular 106 can be used in the blade assembly 102, such as the blades disclosed in patent / patent applications nos. 7,367,396, 7,814,979, 12 / 883,469, 13 / 118,200, 13 / 118,252 and / or 13 / 118,289, whose contents in full are hereby incorporated by reference.
    [00037] The tubular centering system 118 can be configured to locate the tubular 106 in a central location on BOP 104 (as shown, for example, in figure 2). The central location is a location where the drilling tip 300 can be aligned with a central portion 304 of the tubular 106. At the central location, the drilling tip 300 can pierce a wall of tubular 306 of tubular 106 near the central portion 304 of the tubular 106. In order for the drilling tip 300 to pierce tubular 106 in the desired manner, it may be necessary to center tubular 106 before or simultaneously with the engagement of tubular 106 with blade 120.
    [00038] The tubular centering system 118, as shown in figure 3, can have a retractable guide 308 configured to engage the tubular 106 before blade 120. The guide 308 can have any shape suitable for engaging the tubular 106 and moving (or push) the tubular 106 towards the central location as the piston block 208 moves towards the tubular 106. As shown, the guide 308 is a curved, concave or C-shaped surface 310 with an apex 312 that substantially aligns with the drilling tip 300 along a central portion of the surface 310 at an engaging end thereof. Curved surface 310 can engage tubular 106 before blade 120 as piston block 208 moves blade assembly 102 radially toward tubular 106. Curved surface 310 can guide tubular toward apex 312 with continuity of the radial movement of the piston block 208 until the tubular 106 is located near the apex 312.
    [00039] The tubular centering system 118 can have one or more request elements 314 and / or one or more frangible elements 316. The request elements 314 and / or frangible elements 316 can be configured to allow the guide 308 collapse and / or move with respect to blade 120 as blade 120 continues to move towards tubular 106 and / or engage it. Therefore, guide 308 can engage and align tubular 106 with the central location on BOP 104 (as shown in figures 1 and 2). The request elements 314 and / or the frangible element (s) 316 can then allow the guide 308 to move as blade 120 engages and divides tubular 106. Both request elements 314 and frangible elements 316 can be used to allow guide 308 to move relative to blade 120. In addition, both the request element 314 and frangible element 316 can be used together as redundant systems to ensure that piston blocks 208 not be damaged. In the case where both the request elements 314 and the frangible elements 316 are used together, the request elements 314 may need a guide force to move the guide 308 greater than the guide force necessary to break the frangible elements 316.
    [00040] The request elements 314 can be any suitable device to allow the guide 308 to center the tubular 106 and move in relation to the blade 120 with continuous radial movement of the piston block 208. A request force produced by the request elements 314 can be large enough to hold the guide 308 in a guide position until the tubular 106 is centered at the apex 312. With the continuation of the movement of the piston block 208, the request force can be overcome. The request element 314 can then allow the guide 308 to move with respect to the blade 120 as the blade 120 continues to move towards the tubular 106, and / or through it. When the piston block 208 moves back towards the operating position (as shown in figure 2) and / or when the tubular 106 is divided, the request element 314 can move the guide 308 to the starting position, as shown in figure 3. The request elements 314 can be any suitable device for ordering the guide 308, such as a leaf spring, a resilient material, a spiral spring and the like.
    [00041] The frangible elements 316 can be any suitable device to allow the guide 308 to center the tubular 106 and then disengage the blade 120. The frangible element (s) 316 can allow the guide 308 center tubular 106 on BOP 104. Once tubular 106 is centered, the continuity of movement of piston block 208 towards tubular 106 can increase the force on the frangible elements 316 until a disconnecting force is achieved. When the disconnecting force is reached, the frangible element (s) 316 may break, thereby allowing the guide 308 to move or remain stationary as the blade 120 engages and / or pierces the tubular 106. The frangible element (s) 316 can be any suitable device or system to allow the guide to disengage the blades 120 when the disconnecting force is reached, such as a shear pin, and the like.
    [00042] Figure 4 is an alternative view of the blade assembly portion 102 of figure 3. Guide 308, as shown, has apex 312 located at a distance D in the radial direction of the drill tip 300. The centering system of tubular 118 can be located on top 400 of blade 120 in this way allowing an opposite blade 120 (shown in figure 2) to pass close to blade 120 as tubular 106 is divided. The opposing blade 120 may have the tubular centering system 118 located at the base 402 of the blade 120. The piston block 208 can be any suitable piston block configured to support the blade 120 and / or the tubular centering system 118.
    [00043] Figure 5 is another view of the blade assembly portion 102 of figure 3. As shown, the tubular centering system 118 can have a release mechanism (or ferrule) 500 configured to hold the guide 308 in one guide position as shown. The ferrule 500 can be any disturbance, or shoulder, suitable for engaging a surface of the piston block 502. The ferrule 500 can hold the guide 308 in the guide position until the force on the guide 308 increases, and a disconnect force is achieved due to the tubular 106 reaching the summit 312. The continuity of the movement of the piston block 208 can deform and / or displace the ferrule 500 from the surface of the piston block 502. The ferrule 500 can then move along a ramp 504 of the piston block 208 as guide 308 moves relative to blade 120.
    [00044] Figure 6 is another view of the blade assembly 102 of figure 4. The tubular centering system 118 is shown in the guide position. In the guide position, the guide 308 did not move and / or break and is located above the top 400 of the blade 120. The ferrule 500 can be engaged with the surface of the piston block 502 for extra support of the guide 308.
    [00045] Figures 7-17 are schematic views of a portion of a cross section of BOP 104 in figure 2 taken along line 7-7 and representing the blade assembly 102 dividing (or shearing) the tubular 106. Figure 7 shows the BOP 104 in an initial operating position. Blade assembly 102 includes a pair of opposing tubular splitting systems 118A and 118B, blades 120A and 120B and piston blocks 208 AA and 208BB for engaging tubular 106. As shown in each of the figures, the pair of Opposite blades 102 (and their corresponding split systems 118A, B and blades 120A, B) are represented as being the same and symmetrical around the BOP, but can optionally have different configurations (such as those shown here).
    [00046] In the operational position, tubular 106 is free to move through hole 202 of BOP 104 and perform operations at the well site. Piston blocks 208AA and 208BB are retracted from bore 202, and guides 308AA and 308BB of tubular centering systems 118A and 118B can be positioned radially closer to tubular 106 than blades 120A and 120B. Blade assembly 102 may remain in this position until actuation is desired, such as after a disturbance has occurred. When disturbance occurs, blade assembly 102 can be actuated and the split operation can begin.
    [00047] The tubular split systems 118A, B, blades 120A, B and piston blocks 208AA, BB can be the same as, for example, the tubular split system 118, blade 120 and piston block 208 of the figures 3-6. The 118B split system, blade 120B and piston block 208BB are inverted to oppose interaction with the 118A split system, blade 120B and piston block 208BB (shown in a vertical position). Blade 120A (or upper blade) can be blade 120 (as shown in figure 2) configured to face upwards, or move over blade 120B (or lower blade) which can be the same blade 120 in figure 2 configured to face down.
    [00048] Figure 8 shows the blade assembly 102 upon the beginning of the division operation. As shown, piston block 208 AA may have moved blade 120A and tubular centering system 118A into hole 202 and toward tubular 106. Although figures 7-17 show the upper blade 120A (and the block piston 208AA and tube centering system 118A) moving first, bottom blade 120B can move first, or both blades 120A and 120B can move simultaneously. As piston block 208AA moves, guide 308AA engages tubular 106 .
    [00049] Figure 9 shows the blade assembly 102 as the tubular 106 is initially being centered by the guide 308AA. As piston block 208AA continues to move blade 120A and tubular centering system 118A radially towards the center of BOP 104, guide 308AA begins to center tubular 106. Tubular 106 can run along a curved surface 310A of the guide 308AA towards an apex 312A (in the same way as the curved surface 310 and apex 312 of figure 3). As the tubular 106 runs along the curved surface 310A, the tubular 106 moves closer to a center of hole 202, as shown in figure 10.
    [00050] Figure 11 shows the blade assembly 102 as the tubular 106 continues to run along the guide 308AA towards the apex 312A of the curved surface 310A and the other blade 120B (or lower blade) is actuated. The blade 120B can then move radially towards the center of fi ber 202 in order to engage tubular 106.
    [00051] Figure 12 shows the blade assembly 102 as both guides 308AA and 308BB engage the tubular 106 and continue to move the tubular 106 towards the apex 312A and 312B of the tubular centering systems 118A and 118B. The curved surface 310A and a curved surface 310B can match the tubular 106 between the tubular centering systems 118A and 118B as piston blocks 208 AA and 208BB continue to move blades 120A and 120B towards the center of BOP 104.
    [00052] Figure 13 shows tubular 106 centered on BOP 104 and aligned with drilling tips 300A and 300B of blades 120A and 120B. With the tubular 106 centered between the guides 308AA and 308BB, the continuity of the radial movement of piston blocks 208AA and 208BB will increase the strength in the tubular centering systems 118A and 118B.
    [00053] The force can increase in the tubular centering systems 118A and 118B until the requesting force is overcome and / or the disconnecting force is reached. The guide (s) 308AA and / or 308BB can then move, or remain stationary (s) with respect to blades 120A and 120B as piston blocks 208AA and 208BB continue to move. The request force and / or the disconnect force for the tubular centering systems 118A and 118B can be the same, or one can be greater than the other, thus allowing at least one of the blades 120A and / or 120B to engage tubular 106.
    [00054] Figure 14 shows blade 120A piercing tubular 106. Blade 120A moved relative to guide 308AA, thereby allowing drill tip 300A to extend beyond guide 308AA and drill through tubular 106. The centering system from tubular 118B to the blade 120B (or the lower blade) can still be engaged with the blade 120B in this way allowing the guide 308BB to hold the tubular 106 in place as the drilling tip 300A pierces the tubular 106.
    [00055] Figure 15 shows both blades 120A and 120B piercing tubular 106. The tubular centering system 118B moved in relation to blade 120B (or lower blade) thus allowing the drill tip 300B to extend beyond the 308BB guide and pierce tubular 106.
    [00056] Figure 16 shows blades 120A and 120B continuing to shear tubular 106 as piston blocks 208 AA and 208BB move radially towards each other in channel 206. Upper blade 120A is shown passing over a portion of the blade lower 120B. This movement continues until the tubular 106 is divided, as shown in figure 17.
    [00057] Figures 18-27B show various versions of a blade assembly 102a-j and piston blocks 208a-usable as blade sets 102, 102A, 102B and piston blocks 208, 208AA, 208BB described herein. Blade assembly 102a-j may be similar to the previous blade assemblies here, except that blade assemblies 102a-j include a guide 308a-j and an 1840-2740 release mechanism, as will be described herein. The 1840-2740 release mechanism can be used to release the 308A-j guide to move between a guide position engaging the tubular and a cut position at a distance behind an engaging end of the blade (similar to the movement described in the figures 12-17). Guides 308a can be positioned on opposite sides of tubular 106 for engagement with it (similar to the position shown in figures 7-17). The guides 308a-j can be provided with a cavity 1831 to receive a point 1829 of an opposite guide 308.
    [00058] Figure 18 shows the blade assembly 102a including the guide 308a loaded by the piston block 208a. The piston block 208a can have a rear end 1837 that is engageable by a piston (not shown) to move the piston block 208a between an engaging and non-engaging position around the tubular 106. The guide 308a has a front portion 1832 with external portions 1833 and internal springs 1834 extending from them. The outer portions 1833 are slidably receivable by the piston block 208a with the springs 1834 between them. The piston block 208a can be provided with projecting external projections 1835 to slide the external portions 1833 in a sliding way.
    [00059] Internal spring channels 1836 extend into the interior of the guide 308a between each external portion 1833 and the springs 1834. A guide channel 1838 extends between the internal springs 1834 to allow movement between them. The piston block 208a has protruding projections 1842 which can be slidably received by the internal spring channels 1836 to guide the movement of the guide 308a along the piston block 208a. The internal spring channels 1836 and projecting shoulders 1842 can be modeled for sliding engagement between them. The piston block 208a can also be provided with a guide pin 1839 which can be slidably received by the guide channel 1838 to guide the movement of the guide 308a along the piston block 208a.
    [00060] The 1840 release mechanism is a latch 1840 pivoted to the projecting shoulder 1842 of piston block 208a. The latches 1840 can be provided with springs (not shown) to urge the latches to a closed position against the internal springs 1834 to prevent movement of the guide 308a. The latches 1840 and the internal springs 1834 can have shoulders 1843,1844, respectively, for engagement between them.
    [00061] Upon activation, the latches 1840 can move the pivot to an unlocked position outside the internal springs 1834 thereby allowing movement of the guide 308a. Guide 308a can be selectively retractable along piston block 208a upon release by latches 1840. Activation of latches 1840 to release springs 1834 can occur by applying sufficient force (for example, a disconnecting force) to guide 308a. Manual, automatic, mechanical, electrical, or other activations can be used to selectively release the 1840 latches when desired.
    [00062] As also shown in figure 18, the guide 308a may have a concave guide surface 1810 for engaging the tubular. The concave guide surface 1810 may have an apex 1812 along a central axis of the guide 308a. A first portion 1815 of the guide surface 1810 adjacent to the apex 1812 may extend at a first angle cti with the central axis X. A second portion 1817 of the guide surface 1810 may extend from the first portion at a second angle 0.2 with the central axis X.
    [00063] Figure 19 shows another blade assembly 102b with a guide 308b slidably movable along piston block 208b. The blade assembly 102b is similar to the blade assembly 102a, except that the guide channel 1938 between internal springs 1934 is shorter, the protruding external shoulders 1935 are reduced, and the shape of the piston block 208b is modified. The short guide channel 1938 and / or spring channel 1936 can be of a given length to define a travel distance of the guide 308b along the piston block 208b. The rear end 1937 of piston block 208b can be adjusted to receive a piston (not shown). Bosses 1942 and latches 1940 can be positioned to fit the shape of the rear end 1937.The rear end 1937 shown in figure 19 is flat for receptive piston engagement.
    [00064] Blade assembly 102c and piston block 208c of figure 20 are the same as blade assembly 102b of figure 19, except that their portions have been hardened for wear resistance. A 2050 coating has been applied along the contact surfaces of the 2034 inner springs and the 2040 latches. The 2050 coating can be any hardening material (eg titanium nitride or TN) applied to it to facilitate interaction and wear resistance between they.
    [00065] Figure 21 shows a blade assembly 102d with a guide 308d loaded by piston block 208d. The guide 308d is the same as the blade assembly 102b of figure 19, except that the width W of the inner springs 2134 has been increased and the spring channels 2036, shoulders 2042, and latches 2040 have been narrowed. The spring widths W can be selected to provide the desired flexibility for interaction with the latches 2040. The width W of the internal springs 2134 can be selected to provide their desired stiffness, thereby defining the disconnecting force required to activate the latches 2040 for release the 308d guide.
    [00066] Figure 22 shows a blade assembly 102e with a guide 308e. Blade assembly 102e is similar to blade assembly 102d, except that guide 308e has internal springs 2234 and external springs 2235 with spring channels 2236 between them. The outer springs 2235 are positioned between each inner spring 2234 and the outer portions 2232 with an outer spring channel 2238 between them.
    [00067] Double latches 2240 are positioned in spring channel 2236 between inner springs 2234 and outer springs 2235. Double latches 2240 have notches 2242 on either side of them to engage inner spring 2234 on one side and outer spring 2235 on the opposite side of it. The inner springs 2234 and outer springs 2235 can release from the latches 2240 by applying a disconnecting force on the guide 308e.
    [00068] Upon release, the double latches 2240 slide the inner and outer springs 2234, 2235 slidingly to provide sliding movement of the guide 308e along the piston block 208e. As also shown in figure 22, the spring channels 2238 have a modified shape to conform to the modified shape of the double latches 2240.
    [00069] Figures 23-27B show several 102f-j blade assemblies with 308f-j guides with 2340-2740 release mechanisms. Blade sets 102f-je guides 308f-j may be similar to blade sets and guides previously described, except that blade sets 102f-j are provided with several 2360-2760 triggers to activate various 2340-2740 release mechanisms such as will be described here.
    [00070] As shown in figure 23, blade assembly 102f has a guide 308f slidably positioned around piston block 208f and a trigger 2360 along a guide surface 2310. Guide pins 2362 on piston block 208f can be received by displacement slots 2364 to guide the displacement of the guide 308f along the piston block 208f. The guide 308f is also provided with a trigger channel 2366 to receive the release mechanism 2340.
    [00071] Trigger 2360 includes a spring loaded plunger 2368 extending a distance beyond apex 2312 of guide surface 2310 of guide 308f. Plunger 2368 is connected by a rod 2370 to a 2372 element. The 2372 element is slidably positionable in the trigger channel 2366 between a guide position and a cut position in response to the force applied to the 2368 plunger. Guide pins 2367 are positioned on the piston block 208f to slide element 2372 slidably.
    [00072] The release mechanism including a pair of 2340 wedges is positioned in the trigger channel 2366 on either side of the 2372 element. The 2372 element has projections 2374 on either side of it for engagement with the 2340 wedges. With the 2340 wedges positioned on projecting shoulders 2374, wedges 2340 move to a locked position in trigger channel 2366. Trigger channel 2366 has a wide portion 2376 to allow wedges 2340 to extend outward to lock along a ledge 2377 in the trigger channel 2366. With the wedges 2340 positioned along the element 2372 outside the projections 2374, the wedges 2340 move to an unlocked position in the trigger channel 2366. In the unlocked position, the wedges 2340 move to a narrow portion 2378 the trigger channel 2366.
    [00073] The trigger 2360 is activated by applying force along the piston 2368. Such force can be applied as a pressure in the tubular against the piston 2368. Once activated, the force applied on the piston is transferred via the stem 2370 to the element 2372. The element 2372 is moved in such a way that the wedges 2340 move from a locked position on the shoulders 2374 of the element 2372 to an unlocked position outside the shoulders 2374 of the element 2372, and from the wide portion 2376 to the narrow portion 2378 of the trigger channel 2366. In the unlocked position, the guide 308f is free to slide in relation to the piston block 208 between the guide position and the cut position.
    [00074] As shown in figure 24, blade assembly 102g has a guide 308g slidably positioned around piston block 208g. Blade assembly 102g is similar to blade assembly 102f, except that it has a trigger 2460 along the guide surface 2410 and an element 2472 slidably positionable in a channel of the trigger 2466. The trigger 2460 includes a plunger 2468 with a surface of the trigger 2480 along guide surface 2410, and trigger guides 2482 extending into the slots of trigger 2484 on guide 308g. The surface of the trigger 2480 provides an extended contact surface for activation by a tubular and / or an opposite piston block and / or guide along the guide surface 2410.
    [00075] Element 2472 extends from piston 2468 and into trigger channel 2466. Element 2472 is supported in trigger channel 2466 by request elements 2486. Request elements can apply a predefined resistance to movement of element 2472 The element 2472 is slidably positionable in the trigger channel 2466 to engage the release mechanism (or wedges) 2440. The trigger channel 2466 has a wide portion 2476 to move the wedges 2469 to a locked position when positioned along the shoulders 2474 along elements 2472. Trigger channel 2466 also has a narrow portion 2478 for moving wedges 2440 to an unlocked position when positioned off shoulders 2474 along element 2472. Guide pins 2467 are positioned on piston block 208g to receive element 2472 slide.
    [00076] Figures 25 A and 25B show schematic top views of blade assembly 102h including a guide 308h slideable on piston block 208h, and blade 120. Figure 25A shows guide 308h with a guide plate 2586 on it Figure 25B shows guide 308h with guide plate 2586 removed to reveal blade 120 and internal components of guide 308h. Blade set 102h is similar to blade set 102g in figure 24, except that trigger 2560 has a plunger 2568 coupled to a 2572 element by the 2510 stem. Element 2572 is slidably movable in a 2566 trigger channel to activate a mechanism release (or wedges) 2540.
    [00077] The wedges 2540 are coupled to the element 2572 by magnets 2584. The wedges 2540 are selectively extensible by activating the piston 2568 by applying sufficient force to it. Once activated, element 2572 is retracted and wedges 2540 move from a locked position shown in figure 25A to an unlocked position shown in figure 25B. In the locked position of figure 25A, wedges 2540 have fingers 2590 extending from them to engage element 2572. In this position, element 2572 is locked and prevented from moving until piston 2568 is activated. In the unlocked position of figure 25B, the fingers 2590 of the wedges 2540 move to a position above the element 2572. The wedges 2540 have slots 2583 that are slidably positioned at passages 2569 in piston block 208h and the element 2572 is free to retract. In this unlocked position, the guide 308h can retract to a cutting position in such a way that the blade 120 extends beyond the plunger 2568 to cut a tubular.
    [00078] Figures 26A and 26B show schematic top views of blade assembly 102i including a guide 308i slidably positioned on piston block 208i, and a blade 120. Figure 26A shows guide 308i with a guide plate 2686 on it. Figure 26B shows guide 308i with guide plate 2686 removed to reveal blade 120 and internal components of guide 308i. Blade assembly 102i is similar to blade assembly 102g of figures 25A and 25B, except that trigger 2660 has a plunger 2668 with three contacts 2673, 2675 coupled to an element 2672 by the rods 2610.0 element 2672 is slidably movable in trigger channels 2667 to activate a release mechanism (or wedges) 2640.
    [00079] The central contact 2673 has side contacts 2675 on either side of it to provide multiple points of contact for applying a disconnecting force. Rods 2610 connect contacts 2673, 2675 to element 2672 to provide a stabilized structure for smooth sliding movement in the trigger channels 2667 of piston block 208i. The element 2672 also has steps 2665 that provide a positive stop in the trigger channel 2667 against the guide 208i. The wedges 2640 have projections 2683 which move in the passage 2669 in the same way as the wedges 2540 and projections 2583 of figures 25A and 25B.
    [00080] Figures 27A and 27B show schematic top views of blade assembly 102j including a guide 308j slidably positionable on piston block 208j, and a blade 120. Figure 27A shows guide 308j with a guide plate 2786 on it. Figure 27B shows guide 308j with guide plate 2786 removed to reveal blade 120 and internal components of guide 308i. Blade assembly 102j is similar to blade assembly 102i of figures 26A and 26B, except that piston block 208j has guide pins 2784 slidably positioned in guide slots 2785 in the guide, passages 2769 are in fluid communication with tubes 2792 for fluid passes through them, and trigger 2760 and element 2772 have altered shapes. Passages 2769 can be provided to release fluids, such as mud, that can be trapped in the blade assembly 102j. Trigger 2760 has a plunger 2768 with three contacts 2773, 2775 coupled to element 2772 to activate a release mechanism (or wedges) 2740 in a similar manner to trigger 2660 of figures 26A and 26B. As shown in figure 27A, one of the contacts 2775 extends through the guide plate 2786 and into a cavity 2731 for activation by contact with a tip of another guide opposite to it.
    [00081] The operation shown in figures 7-27B show specific sequences of movement and / or blade configurations, guides and components thereof. Variations in the movement order and settings can be provided. For example, the blades and / or guides can be advanced simultaneously or in several orders. Various triggers, release mechanisms and / or guides can be provided to achieve the desired movement of the guide during shearing operations.
    [00082] Figure 28 represents a method 2800 of shearing a tubular from a well hole, such as the well hole 108 of figure 1. The method involves providing 2895 a BOP including a housing with a hole through it to receive the tubular, and a pair of blade assemblies (each of the blade assemblies including a piston block, a blade carried by the piston block, a retractable guide carried by the piston block, and a release mechanism). The method additionally involves moving the piston block 2896 between a non-engaging position and an engaging position around the tubular, selectively releasing the 2897 release mechanism, sliding the 2898 slide between a guide position to guide the engagement with the tubular and a cutting position at a distance behind the blade to allow the blade to engage the tubularly cutting, and to engage the tubularly 2899 with the blade. Additional steps can also be performed, such as retracting the blades and / or guides, and the method can be repeated as desired.
    [00083] Versed in the technique, they realize that the techniques disclosed here can be implemented for automatic / autonomous applications through software configured with algorithms to perform the desired functions. These aspects can be implemented by programming one or more suitable general purpose computers with appropriate hardware. Programming can be performed using one or more program storage devices that are readable by the processor (s) and encode one or more instruction programs executable by the computer to perform the operations described here. The program storage device may take the form, for example, of one or more floppy disks; a CD ROM or other special disk; a read-only memory (ROM) chip; and other forms of the type well known in the art or subsequently developed. The instruction program can be "object code," that is, in binary form that is executable more or less directly by the computer; in "source code" that requires compilation or interpretation before execution; or in some intermediate form such as partially compiled code. The precise forms of the program storage device and instruction encoding are irrelevant here. Aspects of the invention can also be configured to perform the functions described (through appropriate hardware / software) controlled only on site and / or remotely by an extended communication network (for example, wireless, internet, satellite, etc.).
    [00084] Although the modalities are described with reference to various implementations and explorations, it is understood that these modalities are illustrative, and that the scope of the inventive object is not limited to these. Many variations, modifications, additions and improvements are possible. For example, various combinations of blades (for example, identical or not identical), guides, triggers and / or release mechanisms can be provided in various positions (for example, aligned, inverted ) to perform guide and / or division operations.
    [00085] Several cases can be provided for components, operations or structures described here as a single case. In general, structures and functionality presented as separate components in the exemplary configurations can be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component can be implemented as separate components. These and other variations, modifications, additions and improvements may fall within the scope of the inventive object.
    权利要求:
    Claims (12)
    [0001]
    1.Blade assembly (102) of a well plug block to shear a tubular (106) from a well hole (108) that penetrates an underground formation (109), the well plug block having a housing (105) with a hole (202) through it to receive the tubular, the blade assembly (102) comprising: a movable piston block (208) between a non-engaging position and a engaging position around the tubular (106); a blade (120) loaded by the piston block (208) to engage the tubular (106) in a cutting way; characterized by the fact that it also comprises: a retractable guide (308) carried by the piston block (208) and slidably movable along it; and a release mechanism (500) to selectively release the guide (308) to move between a guide position to guide the engagement with the tubular (106) and a cut position at a distance behind the blade (120) to allow the the blade (120) cuts sharply or tubularly (106).
    [0002]
    2. Blade assembly (102) according to claim 1, characterized in that the release mechanism (500) is activated by applying a disconnecting force on a guide surface thereof.
    [0003]
    Blade assembly (102) according to either of claims 1 or 2, characterized in that it additionally comprises a trigger (2360) for activating the release mechanism (500).
    [0004]
    Blade assembly (102) according to claim 3, characterized in that the trigger (2360) comprises a piston (2368) operably connectable in the release mechanism (500).
    [0005]
    Blade assembly (102) according to any one of claims 1 to 4, characterized in that the release mechanism (500) additionally comprises a plurality of wedges (2340) selectively movable between a locked and an unlocked position in the guide.
    [0006]
    Blade assembly (102) according to claim 5, characterized in that it additionally comprises a plurality of projections (2583) carried by the wedges (2340) and selectively movable along a plurality of passages in the guide.
    [0007]
    7. Blade assembly (102) according to claim 6, characterized by the fact that the passages are in fluid communication with tubes extending through the guide for the passage of fluid through them.
    [0008]
    Blade set (102) according to any one of claims 1 to 7, characterized in that the piston blocks have shoulders (1842) for sliding engagement with the guide.
    [0009]
    Blade assembly (102) according to any one of claims 1 to 8, characterized in that the guide surface is concave with an apex (1812) along its central axis.
    [0010]
    10. Blade assembly (102) according to any one of claims 1 to 9, characterized in that a pair of it is used in a well plug block (104).
    [0011]
    11. Method for shearing a tubular (106) from a well hole (108), penetrating an underground formation (109), comprising: providing a well plug block with a pair of blade assemblies as defined in claim 10, characterized as it also comprises: moving the piston block (208) between a non-engaging position and a engaging position around the tubular (106); selectively release the release mechanism (500); slide the guide (308) between a guide position to guide the engagement with the tubular (106) and a cutting position at a distance behind the blade (120) to allow the blade (120) to engage deforming the tubular ( 106); eject the tubular cut (106) with the blade (120).
    [0012]
    Method according to claim 11, characterized in that it also comprises guiding the tubular (106) to a desired position in the well plug block (104) with the guide.
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    同族专利:
    公开号 | 公开日
    CA2812648C|2015-11-24|
    WO2012042269A2|2012-04-05|
    KR101523152B1|2015-05-26|
    EP2622172A2|2013-08-07|
    CN103228866A|2013-07-31|
    WO2012042269A3|2013-03-14|
    EP2622171B1|2014-09-17|
    WO2012042268A2|2012-04-05|
    EP2622171A2|2013-08-07|
    US20120073816A1|2012-03-29|
    SG189079A1|2013-05-31|
    CN103249907B|2016-02-17|
    CN103249907A|2013-08-14|
    US9022104B2|2015-05-05|
    EP2622172B1|2014-09-17|
    SG189080A1|2013-05-31|
    BR112013007701A2|2016-08-09|
    BR112013007713A2|2016-08-09|
    KR20130108375A|2013-10-02|
    US8807219B2|2014-08-19|
    CA2812648A1|2012-04-05|
    WO2012042268A3|2013-03-14|
    US20120073815A1|2012-03-29|
    CA2812646C|2015-11-03|
    KR101523858B1|2015-05-28|
    CA2812646A1|2012-04-05|
    KR20130101065A|2013-09-12|
    BR112013007701A8|2021-02-23|
    BR112013007701B1|2021-03-02|
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-09-17| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-09-01| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-11-24| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 29/09/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US38780510P| true| 2010-09-29|2010-09-29|
    US61/387805|2010-09-29|
    US13/247,517|US8807219B2|2010-09-29|2011-09-28|Blowout preventer blade assembly and method of using same|
    US13/247517|2011-09-28|
    PCT/GB2011/051853|WO2012042269A2|2010-09-29|2011-09-29|Blowout preventer blade assembly and method of using same|
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