Ball seat for high pressure and high temperature

FIELD: oil and gas industry.

SUBSTANCE: group of inventions relates to mining industry and can be used at drilling and completing of wells. An insulating device for a formation fracturing plug includes a ball seat equipped with a mounting surface and a ball having a possibility of contacting to the mounting surface. The mounting surface profile is dome-shaped; the first portion of the profile has a curvature radius that corresponds to the curvature radius of the ball profile, and the second portion has a curvature radius that is larger than that of the first portion. Besides, the invention describes a fracturing plug and an insulation method of zones of a productive formation using an insulating device.

EFFECT: improvement of tightness of an insulating device.

11 cl, 49 dwg

 

The LEVEL of TECHNOLOGY

The technical field

[0002] the Variants of the invention disclosed herein relate mainly to methods and devices for drilling and completions. More specifically, the variants disclosed herein relate to a device for tube rupture and methods isolation zones, using a tube rupture. More specifically, the ways disclosed in this document, refer to the isolating device for tubes rupture.

The level of technology

[0003] During drilling, completion or completion of wells, it is often necessary to isolate specific zones in the well. In some embodiments, for isolating zones in a well injected downhole tools, known as temporary or permanent bridge plugs. The purpose of bridge plugs is to isolate the well from another part of the well. In some embodiments, tube rupture or tube hydraulic fracturing is used to isolate the perforation hole in the well in one area from the perforation hole in another area of the borehole. In other situations, it may be necessary to use the plug-bridge to isolate downhole from the wellhead. These plugs can be removed by drilling through the tube.

[0004] to be Drilled tube generally includes a mandrel, a seal element located in the Rog mandrel, a number of support rings located around the mandrel and adjacent to the seal element, the upper node and lower wedges node with wedges, set around a mandrel, and the upper conical nozzle and the lower conical nozzle, disposed around the mandrel adjacent to the top and bottom nodes with wedges, respectively. In Fig. 1 shows a partial section view of the well 10 with the barrel 12 bore, supplied with a plug 15, which is located in the casing pipe 20 of the wellbore. The tube 15, as a rule, attached to the landing tool and inserted into a hole on a wire rope or casing pipe (not shown), and then is driven, for example, by means of a hydraulic system. As shown in Fig. 1, the wellbore is sealed above and below the tube, so that the oil flowing into the wellbore through the perforation tunnels 23, will be directed to the surface of the well.

[0005] to be Drilled tube can be installed with wire rope, columns coiled tubing or conventional drill string. The tube may be placed in the coupling with the lower end of the landing tool, which includes a lower locking mechanism and the plunger. Then the tube is lowered through the well casing to the desired depth and is guided to the desired orientation. After you install the tube of the landing tool is drawn up on the op is avce, thus pushing the upper and lower conical nozzles along the mandrel. This forces the top and bottom nodes with wedges, support ring and the seal element to move radially outward, thus introducing engages the segmented nodes with the wedges with the inner wall of the casing.

[0006] As shown in Fig. 1B and 1C, the tube 30 break includes a mandrel 32, provided with an axial channel 34 therein, and the saddle 36, located in the channel 34. The saddle 36 is formed to receive the ball 38 to isolate zones of the wellbore and to provide for the extraction of fluid from areas below the tube 30 of the gap. When the top is attached to the differential pressure to the valve seat 36, the ball 38 is attached to the seat 36. For example, when fluid is pumped from the surface through the borehole to the formation fracturing, thus providing increased flow of the fluid reservoir into the wellbore, the ball 38 is adjacent to the valve seat 36 to maintain the fluid and, therefore, breaking the aquifer in the area above the plug 30. In other words, adjacent the ball 38 can prevent the penetration of fluid into the isolated zone, located below the tube 30 of the gap. The ball 38 may be omitted from the surface or can be located inside the mandrel 32 and down the hole in the tube 30 of the gap.

[0007] At high temperatures and pressures, i.e., above about 300°F and is above 10,000 pounds per square inch, commonly used materials for balls wells are not reliable. In addition, conventional ball seat 36 includes a tapering or conical landing surface 40. The ball 38 is in contact with the seat surface 40 and forms a primary seal. Based on the geometry of the Seating surface 40 and the ball 38 there is a large radial distance between the inner diameter of the Seating surface 40 and an outer diameter of the ball. Thus, the bearing surface between the seat surface 40 and the ball 38 is small. When the ball 38 to load sequentially increasing loads, the ball 38 may be subjected to high compressive loads that exceed the limits of the material, thus leading to the destruction of the ball 38. Even if the ball 38 is deformed, it cannot be deformed to an extent sufficient to contact with the conical seat surface 40, and therefore the abutment surface 40 of the ball seat 36 for the ball 38 will remain small. The increase in the ambient temperature can also increase the likelihood of extrusion of the ball 38 through the saddle due to the deterioration of material properties. The mechanical properties of the material of the ball 38 may deteriorate, for example, limits compressive stresses and elasticity, which can lead to an increase in the probability of cracking of the ball or bump through ball the saddle 36. Thus, at high temperature and high pressure environment conventional isolation device for the tubes 30 of the gap, i.e., the balls 38 and the ball seat 36 in the mandrel, can leak or fail.

[0008] If it is desired to remove one or more of these tubes from the wellbore, it is often easier and cheaper to refreservation or webwrite it, than to perform a complicated operation to remove it. When milling, for repressirovaniia devices or at least its external components from the wellbore is used cutter. When drilling for cutting and drilling components tube to remove them from the wellbore, use a drill bit or cutter.

[0009] Accordingly, there is a need for an isolation device for tube rupture, effectively sealing or insulating areas above and below the tube at high temperature and high pressure environment.

The INVENTION

[0010] In one aspect, the variants disclosed herein relate to an insulating device for tube rupture, which includes a ball seat equipped with the seat surface, and a ball adapted to contact with the landing surface, and the profile of the Seating surface corresponds to the profile of the ball.

[0011] In another aspect, the variants disclosed is herein refer to the tube rupture, which includes a mandrel having an upper end and a lower end, the seal element located around a mandrel, and a ball seat located in the Central channel of the mandrel, and the ball seat includes a seat area with a nonlinear profile.

[0012] In the next aspect of the variants disclosed herein relate to a method of isolation zones of the reservoir, including the descent into the well tube rupture to a particular position between the first area and the second area, the installation of the tube in the gap between the first area and the second area, the placement of the ball in the tube rupture and landing of the ball in the ball seat tube rupture, and the ball seat includes a landing surface having a profile that is essentially coincident with the profile of the ball.

[0013] Other aspects and advantages of the invention will be clear from the following description and the accompanying formula.

BRIEF DESCRIPTION of DRAWINGS

[0014] In Fig. 1A presents local incision site tube current level of technology, as it is installed in the wellbore.

[0015] In Fig. 1B shows the cross-sectional view of a conventional ball seat and a ball located in the mandrel tube rupture.

[0016] In Fig. 1C presents an enlarged view of a conventional ball seat and the ball of Fig. 1B.

[0017] In Fig. 2A is redstapler perspective view of a tube rupture in accordance with the variants of the invention.

[0018] In Fig. 2B presents a cross section of the bridge plug gap in accordance with the variants of the invention.

[0019] In Fig. 3A and 3B presents the seal element in accordance with the variants of the invention.

[0020] In Fig. 4 presents a perspective view of a supporting ring in accordance variants of the invention.

[0021] In Fig. 5A and 5B shows in perspective the upper conical nozzle and the lower conical nozzles, respectively, in accordance with the variants of the invention.

[0022] In Fig. 6 shows a partial section of the bridge plug in accordance with the variants of the invention.

[0023] In Fig. 7 presents a perspective view of the mandrel of the bridge plug in accordance with the variants of the invention.

[0024] In Fig. 8 presents a perspective view of site with wedges in accordance with the variants of the invention.

[0025] In Fig. 9 presents a perspective view of the upper gage ring in accordance with the variants of the invention.

[0026] In Fig. 10 presents a perspective view of the lower gage ring in accordance with the variants of the invention.

[0027] In Fig. 11 shows a partial section of the site with wedges in Assembly, the upper conical nozzle and a support node of the element in accordance with the variants of the invention.

[0028] In Fig. 12 presents a cross section of the bridge plug in the unexpanded condition according the variants of the invention.

[0029] In Fig. 13 presents a cross section of the bridge plug of Fig. 12 in the expanded state in accordance with the variants of the invention.

[0030] In Fig. 14 shows a partial section of the bridge plug in accordance with the variants of the invention.

[0031] In Fig. 15 shows a view of a few projections of the seal element in accordance with the variants of the invention.

[0032] In Fig. 16 shows in a few projections of the fragile element support ring in accordance with the variants of the invention.

[0033] In Fig. 17 presents a view of a few projections of the support ring in accordance with the variants of the invention.

[0034] In Fig. 18A and 18B presents a partial cut is not inserted downhole tool and the cross-section is inserted downhole tool, respectively, in accordance with the variants of the invention.

[0035] In Fig. 19A and 19B presents the cross-section component of the downhole tool in accordance with the variants of the invention.

[0036] In Fig. 20A and 20B presents a cross section and top view, respectively, of the component of the downhole tool in accordance with the variants of the invention.

[0037] In Fig. 21A and 21B presents a side view and top view, respectively, of the component of the downhole tool in accordance with the variants of the invention.

[0038] In Fig. 22A and 22B presents Popper is offered cross-section and top view, accordingly, the component of the downhole tool in accordance with the variants of the invention.

[0039] In Fig. 23A, 23B and 23C presents a top view, a side cross section and bottom view, respectively, of the component of the downhole tool in accordance with the variants of the invention.

[0040] In Fig. 24A and 24B presents the cross-section is inserted, and the inserted part, respectively, of the downhole tool in accordance with the variants of the invention.

[0041] In Fig. 25A,25B presents a top view and cross section, respectively, the upper component of the downhole tool in accordance with the variants of the invention.

[0042] In Fig. 25C and 25D is a cross-section and bottom view, respectively, of the lower component of the downhole tool in accordance with the variants of the invention.

[0043] In Fig. 26A and 26B presents a partial section of a component of the downhole tool in accordance with the variants of the invention.

[0044] In Fig. 27 is a partial section of the downhole tool in accordance with the variants of the invention.

[0045] In Fig. 28 shows a partial section of the downhole tools in accordance with the variants of the invention.

[0046] In Fig. 29 presents a partial section of the isolation device in accordance with the variants of the invention.

[0047] In Fig. 29A presents an enlarged view f the, 29.

[0048] In Fig. 30 shows a partial section of the isolation device in accordance with the variants of the invention.

[0049] In Fig. 30A presents an enlarged view in Fig. 30.

DETAILED description of the INVENTION

[0050] In one aspect, disclosed here options embodiments relate mainly to the downhole tool for isolating zones in a well. In certain aspects disclosed here options embodiments relate to a downhole tool for isolating zones in a well, which provides effective sealing of the well. More specifically, variations of the embodiments disclosed herein relate to a device for tube rupture and methods isolation zones, using a tube rupture. More specifically, variations of the embodiments disclosed herein relate to an insulating device for tubes rupture. In other aspects, the variants of the embodiments disclosed herein relate to a system break is not cased wellbore, where the number of profiles saddle is located inside the instrument and balloons fall from the surface and planted on the saddle.

[0051] In Fig. 2A and 2B shows the tube 100 in accordance with one variant of the present invention in the unexpanded state, or after passage through the borehole, but before installation in the wellbore. Unexpanded state definition is seen as a condition in which the tube 100 is lowered in the well, but before application efforts for axial movement of the components of the tube 100 gap and radial expansion of certain components of the tube 100 gap for coupling with the wall of the casing. Tube 100 gap includes a frame 101 having a Central axis 122 around which other parts are mounted tube 100 gap. The frame 101 includes an upper end and A lower end B, and the upper end and A lower end B of the mandrel 101 includes a threaded connection (not shown), for example conical thread. The lower end of the mandrel 101 additionally includes a number of spikes 120 located around the lower circumference of the mandrel 101.

[0052] In one variant embodiment, the mandrel 101 includes a ball seat 103 formed at the same time with the mandrel 101. As shown in Fig. 2B, ball seat 103 formed between the two parts 105, 107 different diameters of the inner channel 134 formed in the mandrel 101. Expert it is clear that the position of the ball seat 103 along the length axis of the mandrel 101 may vary. For example, for certain applications ball seat 103 can be positioned between the end A and the axial position of the seal element 114. In other embodiments, the embodiment of the ball seat 103 can be located between the end and the axial position of the seal element is. In other embodiments, the embodiment of the ball seat 103 can be located at the center along the length axis of the mandrel 101. As shown, the part 105 of the first diameter has a diameter larger than that of the portion 107 of the second diameter. In an alternative embodiment of the ball seat may be formed as a separate part, which is located in the channel 134 of the mandrel 101. Separate ball seat (not shown) can be attached to the mandrel 101 by any known means, such as welding or mechanical fasteners, such as bolt, screw, screw connection.

[0053] the seal Element 114 is located around the mandrel 101. Element 114 seal seals the annular gap between the tube 100 of the gap and the wall of the casing (not shown). The seal element 114 can be formed from any well-known at the present level of material, such as elastomer or rubber. Two guard rings 124, 126 element located around the mandrel 101, near either end of element 114 of the seal radially inside the seal element 114, as shown in the enlarged view of Fig. 3A and 3B. In one variant embodiment of the seal element 114 is connected with an outer peripheral section of guard rings 124, 126 element by any known method. Alternatively, the seal element 114 is pressed with closing rings 124, 126 of the element. The guard ring 124, 126 element which may be a continuous ring or a small tubular parts, formed from any known material, for example, plastic or composite material. The guard ring 124, 126 element have at least one groove or hole 128 formed on the end surface, is formed to receive the protrusion (not shown) formed on the upper end of the conical nozzle 110 and the lower conical nozzle 112, respectively, as described in more detail hereinafter. The specialist will be clear that the number and arrangement of the grooves 128 formed in the guard ring 124, 126 of the element corresponds to the number and position of the protrusions (not shown) formed on the upper and lower conical nozzles 110, 112.

[0054] the Tube 100 of the gap may also include two node 116 of the support element, each of which is located adjacent to the end of the seal element 114 and is formed so as to prevent or reduce extrusion of the seal element 114 by installing the tube 100. Each node 116 of the support element includes two supporting rings. As shown in Fig. 4, the supporting ring 318 in accordance with the variants of the invention is Corky part which has a cylindrical body 330 with the first end surface 332. The first end surface 332 has a round hole so that the supporting ring 318 is formed that is, to slide on the mandrel 101 in the position adjacent to the seal element 114 and a trailing ring 124, 126 of the element. At least one groove 334 formed in the first end surface 332 and formed so as to be aligned with the grooves 128 formed in the guard ring 124, 126 element and to receive the protrusions formed on the upper and lower conical nozzles 110, 112. Expert it is clear that the number and location of grooves 334 formed in the first end surface 332 of the supporting ring 318 corresponds to the number and position of the grooves 128 formed in the guard ring 124, 126 element, and the number and position of the protrusions (not shown) formed on the upper and lower conical nozzles 110, 112.

[0055] the Support ring 318 may be formed from any known material. In one embodiment, the support ring 318 may be made of alloy material, such as aluminum alloy. The number of slots 336 is located on the cylindrical housing 330 support ring 318, each slot 336 extending from the second end 338 of the support ring 318 to a position behind the front end surface 332, thus forming a series of flanges 340. Assembled two supporting rings 318 reference node 116 (Fig. 2B) are aligned so that the slots 336 of the first support ring is offset from the chief who is relatively slots 336 of the second support ring. Thus, when the tube 100 (Fig. 2B) divide installed components and tube rupture compressed, the flange 340 of the first and second support rings radially expand the inner wall of the casing and create a peripheral barrier, which prevents extrusion of element 114 (Fig. 2B) seals.

[0056] As shown in Fig. 2A and 2B, the tube 100 gap includes upper and lower tapered nozzles 110, 112 located around the mandrel 101 and adjacent to the nodes 116 of the support element. The upper conical nozzle 110 may be held in place on the mandrel 101 by one or more shear screws (not shown). In some embodiments, the axial locking device (not shown), such as the retaining ring is located between the mandrel 101 and the upper conical nozzle 110, and between the mandrel 101 and the lower conical nozzle 112. In addition, at least one rotatable locking device (not shown), such as pins, can be located between the mandrel 101 and each of the conical nozzles: the upper 110 and lower 112, thereby securing the mandrel 101 in the tube 100 of the gap during operation of the drilling or milling is used to remove a tube rupture. The top node 106 with wedges and a lower node 108 with the wedges are located around the mandrel 101 and adjacent to the upper and lower conical nozzles 110, 112 with the responsibility. Tube 100 gap, in addition, includes an upper gage ring 102, which is located around the mandrel 101 and connected to the top node 106 with the wedges, and the lower gage ring 104 located around the mandrel 101 and adjacent to the lower node 108 with wedges.

[0057] As shown in Fig. 5A and 5B, the upper and lower conical nozzles 110, 112 are inclined outer surface 442, so that in the assembled mandrel outer diameter of the conical nozzles 110, 112 is increased in the axial direction to the element 114 (Fig. 2B) seals. The upper and lower conical nozzles 110, 112 include at least one protrusion 444 formed on the first end surface 446. At least one protrusion 444 formed so as to coincide with the groove 334 (Fig. 4) formed in the first end surface 332 of the supporting rings 318 node 116 (Fig. 2B) of the support element, and to grapple with the grooves 128 (Fig. 3B) backup rings 124, 126 of the element. Expert it is clear that the number and position of the protrusions 444 corresponds to the number and position of grooves 334 formed in the first surface 332 of the supporting ring 318 and the number and position of the grooves 128 formed in the guard ring 124, 126 of the element.

[0058] As shown in Fig. 2B, the contact protrusions 444 (Fig. 6) the upper and lower conical nozzles 110, 112 interlock with the rotation of the faiths is the Nuits and the lower conical nozzle 110, 112 with the upper and lower nodes 116 of the support element and closing the rings 124, 126 of the element. Thus, in the process of drilling/milling, i.e. drilling/rout out the tube rupture of the casing conical nozzles 110, 112, nodes 116 of the support element and the seal element 114 vibutivalsya easier and faster, because the components do not rotate relative to each other.

[0059] As shown in Fig. 5A and 5B, the upper and lower conical nozzles 110, 112 formed of a metal alloy such as aluminum alloy. In some embodiments, the upper and lower conical nozzles 110, 112 can be formed of a metal alloy and is coated with a different material. For example, in one embodiment, the upper and lower conical nozzles 110, 112 can be covered with copper. The authors of this invention preferably have found that conical nozzles 110, 112, copper-plated, reduce friction between components moving along the inclined surface 442 conical nozzles 110, 112, for example, the nodes 106, 108 (Fig. 2B) with the wedges, thus providing a more efficient and sealed tube (100) gap.

[0060] As shown in Fig. 6, the lower conical nozzle 112 has a first inner diameter D1 and the second inner diameter D2, so that the bearing collar 448 is formed between the first inner diameter D1 and the second inner diameter D2. Not use the collar 448 corresponds to the agreed change in the outer diameter of the mandrel 101, so in the process of drilling or milling mandrel 101 remains in place in the tube 100 of the gap. In other words, the bearing collar 448 prevents the loss of the mandrel from the tube 100 gap in the process of drilling or milling.

[0061] Briefly, again referring to Fig. 5B, the lower conical nozzle 112 includes at least one axial groove 450, located on the inner surface. At least one key groove 154 (Fig. 7) is also formed on the outer diameter of the mandrel 101. If the lower conical nozzle 112 is located around the mandrel 101, the axial groove 450 and the keyway 154 aligned and rotatable locking key (not shown) is inserted into the matching slots on the bottom of the conical nozzle 112 and the mandrel 101. So, once inserted, the rotary lock key locks the rotation of the lower conical nozzle 112 and the mandrel 101 in the process of drilling/milling, thereby preventing their mutual relative movement. The specialist will be clear that the key and the keyway may be of any known form, such as key and the corresponding key groove may have a square cross section or a cross section of another form. In addition, the specialist will be understood that the rotary locking key may be formed from any known material, for example metal alloy.

[0062] As the ANO in Fig. 2A and 2B, the upper and lower nodes 106, 108 with the wedges are located adjacent to the upper and lower conical nozzles 110 and 112. The upper and lower gage ring 102 and 104 are located adjacent to the upper and lower nodes 106, 108 with wedges and contacting them. As shown in Fig. 8, in one variant embodiment, the upper and lower nodes with wedges include fragile locking device 555. Fragile locking device 555 is a cylindrical part having a first end 559 and a second end 561. The number of teeth 557 formed on the first end of 559. The number of teeth 557 formed so as to contact the respective adjacent teeth 662, 664 on the upper and lower gage rings 102, 104, respectively (Fig. 9 and 10).

[0063] the Second end 561 fragile retainer 555 has a conical inner surface 565 formed so as to contact with the inclined outer surfaces 442 of the upper and lower conical nozzles 110, 112 (Fig. 5A and 5B). In addition, the second end 561, which passes from the second end 561 to the position which is close to the teeth 557 first end 559 formed of at least two axial groove 563. Axial grooves 563 spaced circumferentially around the fragile retainer 555 to control the necessary destructive force fragile locking device 555. The number of teeth 71, thread tapered profile or other forms known in the art type formed on the outer surface of the fragile retainer 555 and adapted for grasping or cutting into the wall of the casing. In one embodiment, the fragile retainer 555, including teeth formed from a single component material, for example cast iron.

[0064] In alternative embodiments, as shown in Fig. 11, the nodes with the wedges 106, 108 include wedges 567, located on the outer side of the base 569 wedges. Wedges 567 can be formed in the shape of teeth, tapered thread profile or any other known device for grasping or cutting into the wall of the casing. In some embodiments, the base 569 wedges can be formed from quickly drillable material, while the wedges 567 formed from a rigid material. For example, in one embodiment, the base 569 wedges formed of cast aluminum with a low yield strength, and wedges 567 is formed from cast iron. The specialist will know what can be used other materials and that in some embodiments, the base 569 wedges and wedges 567 can be formed of the same material within the scope of the disclosed variants.

[0065] In Fig. 11 shows a partial view in perspective of a node, consisting of an upper node 106 wedges,top cone nozzles 110 and node 116 of the support element. As shown, the conical inner surface 565 Foundation 569 wedges is located adjacent to the inclined surface 442 of the upper conical nozzle 110. Wedges 567 are located on the outer surface of the base 569 wedges. The protrusions 444 formed on the lower end of the upper conical nozzle 110 inserted through the slots 334 in each of the two support rings 318, which form the node 116 of the support element. As shown, the node 106 with the wedges can provide additional support element 114 (Fig. 2) seal, thus limiting the extrusion of the seal element.

[0066] With reference to Fig. 9, the upper gage ring 102 includes a number of teeth 662 at the lower end. As described previously, the number of teeth 662 formed so as to be linked with a number of teeth 557 upper and lower nodes 106, 108 wedges, for example, fragile retainer 555 (Fig. 8). The upper gage ring 102 also includes internal threads (not shown) formed for threaded connection with the externally threaded axial retaining ring 125 (Fig. 2B) located around the mandrel 101 (Fig. 2).

[0067] As shown in Fig. 2B, the axial retaining ring 125 is a cylindrical part which is provided with an axial cut-out or slot along its length, an external thread and internal thread. As stated previously, the outer thread which cooperates with an internal thread (not shown) of the upper gage ring 102. Inner thread of the axial retaining ring 125 is in contact with the external thread of the mandrel 101. Assembled in the upper gage ring 102 is an axial retaining ring.

[0068] As shown in Fig. 10, the lower gage ring 104 includes a number of teeth 664 on the upper end of 668. As described previously, the number of teeth 664 formed so as to be linked with a number of teeth 557 upper and lower nodes 106, 108 with wedges, for example, fragile retainer 555 (Fig. 8). Inner thread (not shown) formed in the lower end 670 of the lower gage ring 104 and is made to contact with a nipple threaded on the upper end of the second frame, if the number of tubes. In one variant embodiment, the internal thread may be tapered thread. Inner thread (not shown) is also formed on the upper end 668 of the lower gage ring 104 and is made to contact with a nipple threaded on the lower end of the mandrel 101 (Fig. 2B). In the process of drilling/milling of the lower gage ring 104 will be released and fall into the well, being on the top of the lower tube. Due to the rotation of the bit, the lower gage ring 104 will rotate in the fall and to insert or connect the threaded mandrel of the lower tube.

[0069] As shown in Fig. 2-11, after the tube Ara is located in the well in the desired position it is activated or installed, using a set of adapters. Tube 100 may be mounted with the rope, columns coiled tubing or conventional drill string. A set of adapters mechanically stretched on a mandrel 101, simultaneously pushing the upper gage ring 102 and thus moving the upper gage ring 102 and the mandrel 101 in opposite directions. The upper gauge ring 102 pushes the axial retaining ring, the top node 106 with the wedges, the upper conical nozzle 110 and the node 116 of the support element in the direction of the upper end of the seal element 114, and the mandrel pulls the lower gage ring 104, the lower node 108 with the wedges, the lower conical nozzle 112, the rotary locking plug and the lower node 116 of the support element in the direction of the lower end of the seal element 114. As a result, the pushing and pulling effect on upper gage ring 102 and the mandrel 101 compresses the seal element 114.

[0070] the Compression element 114 of the seal element extends seal before contact with the inner wall of the casing, thereby reducing the overall length of the seal element 114. Because the components of the tube rupture is compressed, and the seal element 114 extends adjacent nodes 116 of the support element extend to the coupling with the wall of the casing. If the forces pushing and pulling of the increase, the degree of deformation of ale the NTA 114 seals and components 116 of the support element is reduced. If the degree of deformation of the seal element is negligible, the upper and lower conical nozzles 110, 112 stop moving in the direction of the seal element 114. When the forces of activation reaches a preset value, the teeth 662, 664 of the upper and lower conical nozzles 110, 112, mating with the teeth 557 upper and lower nodes 106, 108 with wedges, destroy the nodes 106, 108 with the wedges on the desired segments, and simultaneously send the segments radially outward until then, until the wedges 557 interlock with the wall of the casing. After power activation reaches a preset value, set the adapter is released from the tube 100 of the gap and the tube is installed.

[0071] As shown in Fig. 12, the tube 1100 break in the unexpanded state shown in accordance with a variant of the present invention. In Fig. 13 shows a tube 1100 break in the unexpanded state. Tube 1100 gap includes a mandrel 1101, item 1114 seal node 1116 support element located adjacent to the element 1114 seals, upper and lower node 1106, 1108 with wedges, the upper and lower conical nozzle 1110, 1112, retainer 1172 and lower sleeve 1174.

[0072] the Mandrel 1101 can be formed as described previously with reference to Fig. 2. For example, the mandrel 1101 may include a solid ball seat, as shown in Fig. 2B, or the roadways or separate ball seat, United with the mandrel. Thread 1176 ratchet is located on the outer surface of the upper end of A mandrel 1101 and formed so as to contact with a locking device 1172. The upper end of A mandrel 1101 includes a threaded connection 1178 formed so as to contact with the screw connection at the lower end of the mandrel, when using a number of tubes. As stated previously, the mandrel 1101 may be formed from any known material, such as aluminum alloy.

[0073] As shown in detail on Fig. 14, the retaining device 1172 includes upper gage ring or housing 1102 retaining ring and an axial retaining ring 1125. If the installation load or force applied to the tube 1100 gap, axial retaining ring 1125 can move or move in one direction along the thread 1176 ratchet located on the outer surface of the upper end of A mandrel 1101. Due to the design of the articulated thread axial retaining ring 1125 and thread 1176 ratchet, after removal of the axial load lock ring 1125 does not move or does not back up. Thus, the retaining device 1172 captures the energy stored in the element 1114 seal from the load during installation.

[0074] in Addition, when the pressure applied from the side of the lower tube 1100 break, the mandrel 1101 mo who should be moved up a little bit, thus resulting in the displacement of the thread 1176 ratchet in one direction to thread through the axial retaining ring 1125, thus additionally putting pressure on the element 1114 seal. Moving the mandrel 1101 does not separate retainer 1172 from the upper node 1106 with wedges, due to the linked profile between the locking device 1172 and base 1569 wedges (or fragile locking device, not illustrated independently) top node 1106 with wedges, described in detail previously.

[0075] As shown in Fig. 12 and 15, item 1114 seal is located around the mandrel 1101. Two guard rings 1124, 1126 element located around a mandrel 1101 and adjacent to any end item 1114 seal, at least a part of each end rings 1124, 1126 element located radially inside the seal element 114. In one embodiment, the element 1114 seal is associated with an outer peripheral section of guard rings 1124, 1126 item by any known method. As a variant, the element 1114 seal pressed with closing rings 1124, 1126 element. The guard rings 1124, 1126 element formed from any known material, for example plastic, phenol-aldehyde polymer or composite material.

[0076] the Guard rings 1124, 1126 element have at least one groove or hole 1128, the SFD is certified on the end surface and formed so to receive a protrusion (not shown) formed on the upper end of the conical nozzle 1110 and the lower conical nozzle 1112, respectively, as described previously with reference to Fig. 2-11. The specialist will be clear that the number and arrangement of the grooves 1128 formed in the guard rings 1124, 1126 element corresponds to the number and position of the protrusions (not shown) formed on the upper and lower conical nozzle 1110, 1112.

[0077] As shown in Fig. 15, the guard rings 1124, 1126 element, in addition, include at least one projection 1180, located on the corner surface 1182 near the outer peripheral edge of the guard rings 1124, 1126 element. The tabs 1180 is formed so as to be inserted into corresponding holes 1184 (Fig. 17) in the supporting ring 1318 (Fig. 17), as described in more detail hereinafter. In some embodiments, the protrusions 1180 may be connected or formed with trailing rings 1124, 1126 element.

[0078] the Nodes 1116 support element located adjacent to the trailing rings 1124, 1126 element and element 1114 seal. The support node 1116 element includes a fragile support ring 1319 and the supporting ring 1318, as shown in Fig. 16 and 17, respectively. Fragile ring 1319 may be formed from any known material, for example plastic, phenol-aldehyde primarily composite material. In addition, fragile ring 1319 may be formed with slots or cutouts 1321 in a given position, so that when the fragile ring 1319 destroyed in the installation process tube 1100 break, fragile ring 1319 segmented in predetermined positions, i.e., the cut-1321.

[0079] the Supporting ring 1318 is a Corky component having a cylindrical housing 1330 with the first end surface 1332. The first end surface 1332 has a round hole so that the supporting ring 1318 is formed so as to slide on the mandrel 1101 in a position adjacent to the element 1114 sealing and closing ring 1124, 1126 element. At least one groove 1334 formed in the first end surface 1332 and formed so as to be aligned with the grooves 1128 formed in the guard rings 1124, 1126 element, and to accept the protrusions formed on the upper and lower conical nozzle 1110, 1112. The specialist will be clear that the number and location of grooves 1334 formed in the first end surface 1332 support ring 1318, corresponds to the number and position of the grooves 1128 formed in the guard rings 1124, 1126 element, and the number and position of the protrusions (not shown) formed on the upper and lower conical nozzle 1110, 1112. In addition, a number of holes 1184 formed in a first of the end surface 1332 support ring 1318 and designed to accept the protrusions 1180 end rings 1124, 1126 element. Thus, the protrusions 1180 interlock with the rotation of the node 1116 support element with the element 1114 seal. The specialist will be clear that the number and position of the holes 1184, formed in the first end surface 1332 support ring 1318, corresponds to the number and position of the protrusions formed in the guard rings 1124, 1126 element.

[0080] the Number of slots (not shown) is located on the cylindrical housing 1330 support ring 1318, each slot extending from the second end 1338 support ring 1318 to the position behind the front end surface 1332, thus forming a number of flanges (not shown). When the installation load is attached to the tube 1100 break, fragile support ring 1319 dissolved into segments. The segments are expanded and in contact with the casing pipe. The distance between the segments in contact with casing pipe, is essentially the same as the tabs 1180 guard rings 1124, 1136 item send segmented fragile support ring 1319 in place. When the tube 1100 break attached mounting the load support ring 1318 expand, and the flanges of the supporting rings 318, located at each end of the element 1114 seal, radially expanding the inner wall of the casing t is UBA. Extended flanges close any space between segments fragile support rings 319, thereby creating a peripheral barrier, which prevents the extrusion element 1114 seal.

[0081] As shown in Fig. 12 and 14, top and bottom nodes 1106, 1108 with wedges formed so as to secure the tube 1100 to break the casing pipe and to withstand subsequent high load, when the tube 1100 break attached pressure. The upper and lower nodes 1106, 1108 with wedges include a base 1569 wedges, wedges 1567 and bearing 1587 wedges. The upper and lower nodes 1106, 1108 with wedges are located near the upper and lower conical nozzles 1110, 1112, respectively, so that the conical inner surface of the base 1569 wedges formed so as to contact with the inclined surface 1442 conical nozzles 1110, 1112.

[0082] the Base 1569 wedges top node 1106 with wedges includes a locking profile 1599 upper surface of the base 1569 wedges. The locking profile 1599 formed so that the upper base 1569 wedges in contact with the upper gage ring 1102. Thus, the upper gage ring 1102 includes a corresponding locking profile 1597 on the bottom surface. For example, the retaining profiles 1599, 1597 can be connected L-shaped protrusions, as shown in the view of the D Fig. 14. As described earlier, these locking profiles 1597, 1599 secure the base 1569 wedges to the upper gage ring 1102 if any pressure drop through the tube 1100 gap, thus supporting the activation element 1114 seal. In addition, L-shaped protrusions, probably less prone to destruction than the typical T-shaped connection, and probably more effective vibutivalsya in the process of drilling/rout out.

[0083] Wedges 1567 may be formed in the shape of teeth, tapered thread profile or any other known device for grasping or cutting into the wall of the casing. In one embodiment, the wedges 1567 may include the locking profile that allows you to mount wedges 1567 based on 1569 wedges without additional fasteners or adhesives. The locking profile includes a protruding portion 1589, located on the inner diameter of the wedge 1567 and shaped to be inserted into the base 1569 wedges, thus securing the wedge 1567 based on 1569 wedge. The protruding portion may 1589, for example, be in the form of a hook or L-shaped ledge for secure attachment of the wedge 1567 to the base 1569 wedges. The specialist will be clear that the protrusions with different shapes and/or profiles can be used without deviation from the scope of disclosed cases.

[004] the Base 1569 wedge may be formed from quickly drillable material, while wedges 1567 formed from a rigid material. For example, in one variant embodiment, the base 1569 wedges formed of cast aluminum with a low yield strength, and wedges 1567 formed from cast iron. Alternatively, the base 1569 wedges may be formed of aluminum alloy 6061-T6, while the wedges 1567 formed of malleable cast iron, treated with induction heating. The specialist will know what can be used other materials and that in some embodiments, the base of the wedge or wedges may be formed of the same material within the scope of the disclosed variants.

[0085] the Thrust ring 1587 wedges are located around the base 1569 wedges for fixing the base 1569 wedges to the tube 1100 gap before installing. Retainer rings 1587 wedges usually are cut at a load of about £ 16000-18000, thus activating the nodes 1106, 1108 with wedges. After the activation of the nodes 1106, 1108 with wedges radially expanded to contact with the wall of the casing. As soon as the wedges 1567 in contact with the wall of the casing, the portion of the load applied to the element 1114 seal, is used to overcome the braking between the teeth of the wedges 1567 and the wall of the casing.

[0086] As shown in Fig. 18A and 18B, the tube 2200 gap, in accordance with a variant of this izopet the tion, shown in the uninstalled position and in the prescribed position, respectively. In some embodiments, the tube 2200 gap can be made so as to withstand high pressure and high temperature environment. High pressure and high temperature environment can adversely affect the efficiency of the seal components. In particular, in viborgvej tubes rupture of high ambient temperature can cause degradation and weakening of the material of the seal elements. When exerting high pressure, degraded material of the seal elements may begin to crowded or pushed out through any gaps in the supporting structure surrounding the elements of the seal. In this case, the efficiency of the seal element may be lost. Disclosed here can provide a downhole tool, such as, for example, tube rupture, capable of withstanding high temperature and high pressure environment.

[0087] Tube rupture 2200 may include a mandrel 2202 having the upper end 2204 and the lower end of 2206. The upper conical nozzle 2210 may be located above the upper node 2208 with wedges. The top node 2208 with wedges, which includes klinovuyu the pad 3004 and teeth 3002, as shown in detail in Fig. 26A and 26B, may be positioned around the upper end of the mandrel 2202 above the upper conical nozzle 2210. The top node 2212 ring may be positioned around the mandrel 2202 above the element 2214 seal and may include the inner support ring 2500, the outer support ring 2600 and the support ring 2700, as shown in Fig. 21A and 21B, Fig. 22A and 22B, and Fig. 23A, 23B, and 23C, respectively. Element 2214 seal may include upper and lower guard rings 2402, 2404 (shown in Fig. 20A and 20B) on the upper and lower ends 2216, 2218 element 2214 seals, respectively. In some embodiments, the element 2214 seal may be formed from an elastomeric material, for example, hydrogenated nitrile rubber, nitrile or forecasters, such as Aflas®. The upper and lower guard rings 2402, 2404 may be formed from fibrous plastic impregnated with phenolformaldehyde. In some embodiments, the upper and lower guard rings 2402, 2404 can be accommodated in the mold element seal prior to filling the mold with the material selected for forming the element 2214 seal. In such embodiments, the element 2214 seal can be formed together with the upper and lower trailing rings 2402, 2404, so that the element 2214 seals and the upper and lower guard rings 2402, 2404 formed of a single item.

[0088] the Lower node 2220 rings can be located under the lower end of the ring is m 2404 element 2214 seal and may include the inner support ring 2500, the outer supporting ring 2600 and the support ring 2700 shown in Fig. 21A and 21B, Fig. 22A and 22B, and Fig. 23A, 23B, and 23C, as described above, with reference to the top node 2212 rings. The lower conical nozzle 2222 may be located around the mandrel 2202 below the bottom node 2220 ring, and the bottom node 2224 with wedges may be positioned at the bottom of the conical nozzle 2222. The bottom node 2224 with wedges may include klinovuyu the pad 3004 and teeth 3002, as shown in detail in Fig. 26A and 26B. The lower sleeve 2226 may be connected with the lower end 2206 mandrel 2202.

[0089] To move the tube 2200 gap from the uninstalled position to the installed position can be used boarding tool for the application raises an axial force to the mandrel 2202 while lowering application of axial force to the parts located around the mandrel 2202. In some embodiments, raising the axial force applied to the mandrel 2202 may be transferred to the bottom of the sleeve 2226, to the lower node 2226 with wedges to the bottom of the conical nozzle 2222 using different connections between the parts. In addition, lowering the axial force applied to the parts located around the mandrel 2202 may be transmitted to the upper node 2208 with wedges and the upper conical nozzle 2210. And raising and lowering of the axial force can then be transmitted from the upper and lower conical nozzles 2210, 2222 to the element 2214 seals and the upper and lower nodes 2212, 2220 rings, thus causing deformation of the lower nodes 2212, 2220 rings and element 2214 seal. In some embodiments, the element 2214 may be formed so as to deform the desired area so that the radial expansion in the outer direction occurred at a critical value of pressure. Radial deformation in the outer direction may cause the contact element 2214 seal with the wall of the outer casing 2228 and may form a seal.

[0090] In Fig. 19A and 19B shows a view of the cross-section of the mandrel 2202. Slots 2302 may be formed on the lower end 2206 mandrel 2202. As shown in Fig. 19B, slots 2302 are straight slots, but the specialist will be clear that can be used in the slots of the other geometry, such as, for example, the spiral slots. Slots 2302 can be designed for engagement with corresponding slots located on the inner surface of the lower conical nozzle 2222 (Fig. 18A, 18B). In selected embodiments, the engagement of the slots 2302 with the corresponding slots on the bottom of the conical nozzle 2222 may prevent relative rotation between the mandrel 2202 and the lower conical nozzle 2222.

[0091] With reference to Fig. 20A and 20B shows the kinds of the cross-section of the element 2214 seal. The upper trailing number of the TSO 2402 may be located near the upper end 2216 element 2214 seal, and the lower end ring 2404 may be located near the lower end 2218 element 2214 seal. In some embodiments, the upper and lower guard rings 2402, 2404 can be decorated with the upper and lower fingers clutch 2403, 2405, made so as to be coincident with the corresponding fingers 2902, 2903 on the upper and lower conical nozzles 2210, 2222, respectively, as will be described later with reference to Fig. 24A. As previously described, upper and lower trailing rings 2402, 2404 may be formed from fibrous plastic impregnated with phenolformaldehyde. Alternatively, the upper and lower guard rings 2402, 2404 may be formed from die-cast thermoplastic. In some embodiments, the upper and lower guard rings 2402, 2404 can be pressed into the element 2214 seal; however, the specialist will be clear that we can use other means to connect the upper and lower guard rings 2402, 2404 with element 2214 seal. As shown in Fig. 20A, the element 2214 seals is unknown. Portion 2408 of reduced width may be located on the inner surface 2406 element 2214 seal. When installing the downhole tool may be a compression element 2214 seal, thus causing swelling element 2214 seals on the part 2418 with smart the perfect width and extending radially outward and in contact with the outer hollow or casing pipe (not shown). In this embodiment, the amount of compression that is attached to the element 2214 seal may correspond to the radial force element 2214 seal in the casing pipe.

[0092] Now, referring to Fig. 21A and 21B shows a cross section and top view, respectively, of the inner support ring 2500 in accordance with open options here. The inner support ring 2500 may include a radial portion 2502, essentially perpendicular to the longitudinal axis 2508 downhole tool. The inner support ring 2500, having an outer diameter 2516 may also include an axial portion 2506, essentially parallel to the longitudinal axis 2508, and a corner portion 2504, located between the radial and axial portions 2502, 2506. As shown, the inner support ring 2500 can be divided into segments 2510 slots 2514. In addition, a number of cut-2512 may be arranged in the radial part 2502 inner support ring 2500 and more are described below.

[0093] In Fig. 22A and 22B outer supporting ring 2600 in accordance with the disclosed here options shown in cross-section and top view, respectively. The outer supporting ring 2600 may include a radial portion 2602, essentially perpendicular to the longitudinal axis 2508 downhole tool. The outer supporting the ring 2600 may, in addition, include an axial portion 2606, essentially parallel to the longitudinal axis 2508, and a corner portion 2604, located between the radial and axial portions 2602, 2606. The number of cutouts 2612 can be located in the radial portion 2602 of the outer support ring 2600. In addition, the outer support ring 2600 may include facing 2608 on the inner surface of the outer support ring 2600, as shown in Fig. 22A. In some embodiments, the cladding 2608 may be formed from a plastic material, which can provide radial expansion of the lining 2608. Facing 2608 may be formed from an elastomeric material such as, for example, hydrogenated nitrile rubber, nitrile, PTFE or fluoroelastomer, such as Aflas®. The outer supporting ring 2600 and facing 2608 may have an internal diameter 2616, where the inner diameter 2616 essentially has the same size as the outer diameter 2516 inner support ring 2500. Alternatively, between the inner diameter 2616 outer support ring 2600 and an outer diameter 2516 inner support ring 2500 may be a small gap.

[0094] With reference to Fig. 23A, 23B, and 23C shows a top view, cross section and bottom view of a supporting ring 2700 in accordance with disclosed the options here. Slots 2712 can split support ring 2700 segments 2710. As shown in Fig. 23B and 23C, each segment 2710 may include a protrusion 2702 formed so as to engage with a corresponding profile 2701, 2703 upper and lower conical nozzle 2210, 2222, respectively, as shown in Fig. 24A. Support ring 2700 can be located near the outer supporting rings 2600 above and below the element 2214 seal, as shown in Fig. 24A and 24B. When the tube 2200 gap installed, support rings 2700 may be subjected to forces of compression. Support ring 2700 can be formed from such material, as a result of the impact forces of the compression segments 2710 support rings 2700 can be separated and to expand radially outward to contact with the wall 2228 casing, as shown in Fig. 24B. In some embodiments, the support ring 2700 may be formed of phenolic material. Torn segments 2710 support ring 2700 can provide support against extrusion element 2214 seal through the gaps in the inner and outer supporting rings 2500, 2600 by providing a stable surface on which the inner and outer supporting rings 2500, 2600 can be deformed uniformly. In addition, torn segments 2710 support ring 2700 can add support for internal and darwinopterus rings 2500, 2600 and can provide an additional sealing surface on the wall 2228 casing, which may block the extrusion element 2214 seal.

[0095] As shown in Fig. 24A, shows the cross-sectional unidentified downhole tool in accordance with the disclosed here options. The inner support ring 2500 can be collected adjacent to the upper and lower trailing rings 2402, 2404, which can be located near the upper and lower ends 2216, 2218 element 2214 seal. The outer support ring 2600 can be placed next to the inner support rings 2500, so that the inner support ring 2500 placed in the socket in the outer supporting rings 2600. In some embodiments, inner and outer supporting rings 2500, 2600 can be positioned so that the axial portion 2506, 2606 pass to overlap the upper and lower guard rings 2402, 2404 on the element 2214 seal. As shown in Fig. 24B shows a view of the cross-section is installed downhole tool in accordance with the disclosed here options. When the radial expansion of the element 2214 seal, which occurs when installing tube 2200 gap, the axial portion 2506, 2606 and the angular portion 2504, 2604 inner and outer supporting rings 2500, 2600, respectively, can be deformed to radial expansion due to their overlap with the element 2214 seal. Slots 2514, 2614, forming segments 2510, 2610 on both inner and outer barriers 2500, 2600, can provide radial expansion of the inner and outer barriers 2500, 2600 before contact with the outer wall 2228 hollow or casing. With this design with a radial extension, inner and outer supporting rings 2500, 2600 may have gaps where diverging slots 2514, 2614. To prevent extrusion of the element 2214 seal through the gaps, inner and outer supporting rings 2500, 2600 can be shifted so that the slot 2514 inner support ring 2500 combined with segment 2610 outer support ring 2600 and, accordingly, the slot 2614 outer support ring 2600 combined with segment 2510 inner support ring 2500. Besides, facing 2608, located on the outer support ring 2600 may contact the inner support ring 2500 and embossed in any gaps between the inner and outer supporting rings 2500, 2600, thus filling the gaps and providing additional support against extrusion element 2214 seal through the gaps in the inner and outer supporting rings 2500, 2600.

[0096] For maintaining the appropriate alignment of internal and darwinopterus rings 2500, 2600 relative to each other and relative to the element 2214 seals, upper and lower fingers 2902, 2903 clutch on the upper and lower conical nozzles 2210, 2222 can engage with cutouts 2512, 2612, located in the inner and outer supporting rings 2500, 2600, so as to prevent relative movement between the inner and outer supporting rings 2500, 2600. In addition, the upper and lower fingers 2902, 2903 coupling the upper and lower conical nozzles 2210, 2222 can engage with the respective upper and lower fingers 2403, 2405 coupling the upper and lower guard rings 2402, 2404 element 2214 seal, thereby preventing relative movement between the inner and outer supporting rings 2500, 2600, element 2214 seals and the upper and lower conical nozzles 2210, 2222.

[0097] As shown in Fig. 25A, 25V, 25C and 25D, shows the upper and lower conical nozzle in accordance with the disclosed here options. The upper conical nozzle 2210 shown in the top view and in cross section in Fig. 25A and 25B, respectively, and the lower conical nozzle 2222 shown in cross section and bottom view in Fig. 25C and 25D, respectively. As described previously, the upper conical nozzle 2210 and lower conical nozzle 2222 may include upper fingers 2902 clutch andlower fingers 2903 clutch, respectively, are made so as to engage with the upper and lower fingers 2403, 2405 coupling the upper and lower guard rings 2402, 2404, respectively, of the element 2214 seal through openings 2512, 2612 inner and outer supporting rings 2500, 2600 (Fig. 21A, 21B, 22A, and 22B). The upper and lower conical nozzle 2210, 2222 may also include a number of guides 2908 wedge pads located on the outer surface of the upper and lower conical nozzles 2210, 2222, formed to receive the upper and lower nodes 2208, 2224 with wedges, respectively. Guides 2908 wedge pads may be located at an angle relative to the longitudinal axis 2508.

[0098] As shown in Fig. 26A and 26B, shows the components of the node 2224 with wedges in accordance with the disclosed here options. Wedge plate 3004 shown as provided with a profile 3012a of teeth designed to engage with a corresponding profile 3012b of teeth located on the number of outer teeth 3002. In addition, the locking hook 3006 may extend downward from the outer teeth 3002 and can be made to lock in the corresponding cutout 3014 locking hook located in the wedge plate 3004. In some embodiments, for compounds V-pads 3004 with external teeth 3002 may include a combination of siteplease the Xia paired profiles 3012a, 3012b teeth and connecting the paired locking hook 3006 with a cutout locking hook 3014.

[0099] the Node wedge pads 3004 and outer teeth 3002 may be formed so as to be mounted in each rail 2908 wedge pads. During installation of the downhole tool wedge pads 3004 can move in the guide 2908 wedge pads to push the outer teeth 3002 in the wall of the casing (not shown). Guides 2908 wedge pads can help align V-pads 3004 and outer teeth 3002-axis along the sides of the casing (not shown), so that the adhesion between the teeth 3002 wedge plates and the wall of the casing could be distributed evenly. Guides 2908 wedge pads may also include copier 2910 wedge pads are formed so as to provide additional support under the direction of a number of wedge pads 3004 and outer teeth 3002 along the guides 2908 wedge pads during installation of the downhole tool. As shown in Fig. 26B, the wedge plate 3004 may include a shank 3010 copier, designed to engage and be moved along copier 2910 wedge pads.

[00100] In some embodiments for attaching the node wedge pads 3004 and outer teeth 3002 in place relative the upper and lower conical nozzles 2210, 2222 can be used by the holder of wedges (not shown) until it reaches a critical pressure during installation of the downhole tool. When the critical pressure of the holders of wedges (not shown) may terminate, thus ensuring the movement of wedge pads 3004 and outer teeth 3002 along the guide wedge pads 2908 and copiers wedge pads 2910 before the coupling with the wall of the casing (not shown). The specialist will be clear that the holders of the wedges can be designed to terminate at any desired value of a force or pressure. For example, geometry, material, processing technology holder wedges and other factors can change to obtain the holder of the wedges, which terminates at a given critical pressure. In some embodiments, the holders of the wedges can be designed for a force of about £ 16000-18000. The expert also it will be clear that, until the termination of holders of wedges, all the pressure exerted during the installation of the downhole tool, focused on the deformation element 2214 seal, so that there is radial extending outward and grip seal with the wall of the casing (not shown). Thus, the holder of the wedges is designed to withstand high pressure, provides applied the e high pressure to the element 2214 seal, conversely, the holder of the wedges is designed to withstand low pressure, provides only the application of low pressure to the element 2214 seal before V-pads 3004 and outer teeth 3002 get the ability to move and grip the sides of the casing (not shown). In some embodiments, the outer teeth 3002 can be heat treated to obtain the desired properties of the material used, such as induction heat treatment. In some embodiments, the induction heat treatment of the outer teeth 3002 can increase the strength of the outer teeth 3002 and can reduce the probability of occurrence and growth of cracks.

[00101] As shown in Fig. 27 shows an enlarged view of the cross section of tube rupture in accordance with the present invention. Retainer 2230 shown as provided with an upper sleeve 2203 profile 3108a ratchet located on its inner side. The upper sleeve 2203 shown as located around the upper end of the mandrel 2204 2202, and around the sleeves 3106 ratchet. Profile 3108b ratchet can be located on the outer surface of the sleeve 3106 rattles, and can be made so as to match the profile 3108a ratchet on the upper sleeve 2203. In addition, the inner surface of the sleeve 3106 ratchet may include a threaded portion formed by the second well, to connect carving with corresponding threads located on the outer surface of the mandrel 2202. Alternatively, the specialist will be clear that we can use other means to connect the sleeve 3106 ratchet and mandrel 2202, such as other mechanical, adhesive or welded connection.

[00102] As described previously, to install the tube 2200 gap to the upper sleeve 2203 may be accompanied by lowering the axial force, while the mandrel 2202 enclosed lifting the axial force. Because the element 2214 seal is compressed and deformed outward, the details surrounding the mandrel 2202, closely compressed together. The retaining device 2230 may ensure that the amount of compression achieved when installing the instrument in the setup process are maintained at the same level after installation tool installation or removal efforts. Adjusting the profile 3108a, 3108b can be performed so that the shouldered essentially perpendicular to the longitudinal axis 2508, let the movement of the upper sleeve 2203 up the axle relative to the mandrel 2203. In addition, in some embodiments, the shear screw 3110 can connect the upper sleeve 2203 with the mandrel 2202, so moving down the upper sleeve 2203 relative to the mandrel 2202 is prevented, until then, until the applied axial force, dostat is offered for cutting shear screws 3110. The specialist will be clear that the effort required for cutting shear screws 3110, may depend on a number of factors, such as geometry, material and heat treatment shear screws 3110.

[00103] In some situations, you may need to uninstall your plug gap. Due to the high cost of time, labor and tools associated with removal of tube rupture, using retrieved from the well tool may be more cost-effective drilling or milling tube rupture, and the design and materials of each component tube rupture can be selected, referring to this end. With reference to Fig. 28, the upper tube 2200 gap is shown located in the casing pipe 2228 above the bottom tube 2200b gap. Slots 2302 mandrel 2202a shown in engagement with the corresponding slots 2904 on the bottom of the conical nozzle 2222. The slots may prevent rotation of the parts of the tube 2200 a break during the drilling operation and thus can increase the effectiveness of the procedure.

[00104] the Upper tube 2200 gap is shown as provided with a lower sleeve 2226 below the lower cone nozzle 2222 and includes a number of discharge grooves 3202 on its outer surface. The discharge grooves 3202 can act as stress concentrators to increase the speed of the process of drilling by facilitating the breaking of the material of the lower sleeve 2226 when drilling. In addition, the lower surface 3212 of the mandrel 2202a can cut the first row of slots 3214, so that when reached a certain position of the mandrel with the tool for drilling, the remaining material between the slots 3214 may break off. Similarly, on the bottom surface 3208 lower sleeve 2226 can be located slots 3210 to increase the speed and efficiency of the drilling tube 2200 gap.

[00105] as soon As the exciting details, such as the outer teeth 3002, drilled, remains smaller bearing area for the retention tube 2200 gap on the spot. In some embodiments, the portion of the lower sleeve 2226 may be exempted from tube 2200 a break during the drilling operation. The lower sleeve 2226 may include an internal tapered thread 3204 made to engage with external tapered threads 3206, located on the upper end of the mandrel 2202b lower tube 2200b gap. In some embodiments, the drilling of the upper tube 2200 may cause lower sleeve 2226 will rotate with the tool for drilling. In this embodiment, since the lower sleeve 2226 top tube 2200 a tear falls on the mandrel 2202b lower tube 2200b gap, the lower sleeve 2226 may be rotating. In some embodiments, the internal taper threads 3204 lower sleeve 2226 can log in for the Alenia with external tapered threads 3206 mandrel 2202b, rotational movement of the sleeve 2226 can provide sufficient torque to perform a threaded connection. Such a property can provide the tool for drilling, the drilling efficiency of the remaining part of the lower sleeve 2226, while it is connected on the threaded mandrel 2202a. In addition, a number of ribs 2227 may be located on the outer surface of the lower sleeve 2226 and may extend radially outward. In this embodiment, when the sleeve 2226 rotates and drops down, fin 2227 can remove debris from the inner wall 2228 casing, scraping accumulations of debris.

[00106] In Fig. 29 shows the isolation device 4001 tube rupture (not shown) in accordance with the variants of the invention. Isolation device 4001 includes a ball seat 4003, located in the axial channel 4005 mandrel 4007 tube rupture, and the ball 4009. As shown, ball seat 4003 can be formed simultaneously with the mandrel 4007, so that the mandrel 4007 has a first inner diameter 4011 and the second inner diameter 4013, and the second 4013 inner diameter smaller than the first inner diameter 4013. Saddle 4003 is formed in the transition portion of the inner diameter of the mandrel 4007, between the first inner diameter 4011 and the second inner diameter 4013. In another embodiment, the ball seat 4003 may be a separate piece that is installed in the channel 4005 about what rivki 4007 and connected to the mandrel 4007. In one embodiment, the mandrel 4007 and ball seat 4003 can be made of a metal material such as aluminum. Alternatively, the mandrel 4007 and saddle 4003 can be made from plastic or composite material, known state of the art. In addition, the specialist will be understood that the mandrel 4007 may be made of a material different from the material ball seat 4003.

[00107] the Ball 4009 is a spherical device designed to contact or landing in the saddle 4003. In one embodiment, the ball 4009 may be made from plastic or composite materials. In some embodiments, the ball 4009 may be made of phenol-aldehyde resin and glass fiber composite material. The specialist will be clear that the ball 4009 may be made of other known materials, including other fibrous materials and polymers. The material of the ball 4009 may be selected based on the temperatures and pressures expected environment in which is located a tube rupture.

[00108] As shown in Fig. 29 and in the enlarged view of Fig. 29A, saddle 4003 provided in the seat surface 4015, having a dome-shaped profile. As shown, the profile of the Seating surface 4015 corresponds to the profile of the ball 4009. In particular, as shown in Fig. 29A, the profile of the Seating surface 4015 - curve. Dome-shaped refill may be spherical or elliptical. Thus, the radius of curvature of the dome-shaped profile may be constant or variable. The radius of curvature of the Seating surface 4015 may be approximately equal to the radius of curvature of the ball 4009. Thus, in one embodiment, the landing surface 4015 provides inverted dome-shaped saddle with a channel therein formed to receive the ball 4009.

[00109] In one embodiment, the saddle 4003 may include a first section 4017 and the second section 4019. The first section 4017 is located on an axis above the second section 4019. In this embodiment the first section 4017 may include a cone-shaped profile forming a conical surface. The second section 4019 may include a profile corresponding to the profile of the ball 4009. When the ball 4009 omitted or when he moves down inside the tube rupture, if the above tube rupture is attached to the pressure differential, the first section 4017 can help center or send the ball 4009 in the saddle and in contact with the second section 4019.

[00110] As shown in Fig. 30 and in the enlarged view of Fig. 30A, saddle 5003 tube rupture in accordance with the disclosed here, the options may include the landing surface 5015, has a profile. As shown, the profile of the Seating surface 5015 essentially corresponds to the profile of the ball 5009. In particular, as shown in Fig. 30A, the profile of the Seating surface 5015 includes a number of separate areas 5015a, 5015b, 5015c, 5015d, which together form a continuous profile to match the profile of the ball 5009. In some embodiments, the profile of the Seating surface 5015 may include 2, 3, 4, 5 or more separate parts. Separate areas may be linear or dome-shaped. For example, in one embodiment, each individual plot has a radius of curvature that is different from every other individual parcel. Alternatively, each segment may have the same curvature radius, but the radius of curvature of each individual parcel is less than the radius of curvature of the ball 5009. In another embodiment, each segment may be linear and may include an angle relative to the Central axis of the mandrel 5007 or ball seat 5003 different from every other corner of the section. The average public profile Seating surface 5015 is the profile, which essentially corresponds to the profile of the ball 5009.

[00111] In one embodiment, the saddle 5003 may include a first section 5017 and the second section 5019. The first section 5017 is located on an axis above the second section 5019. In this embodiment the first section 5017 may include a tapered profile such that it forms a conical surface. The second section 5019 may include profile, essentially corresponding to the profile of the ball 5009. When the ball 5009 omitted or when onpremises down inside the tube rupture, if the above tube rupture is attached to the pressure differential, the first section 5017 can help center or send the ball 5009 in the saddle and in contact with the second section 5019.

[00112] As shown in Fig. 29 and 30, since the ball seat 4003, 5003 has a profile corresponding to the profile of the ball 4009, 5009, radial clearance between the ball 4009, 5009 and the seat surface 4013, 4015 - small. In addition, the geometry (i.e. profile) seat 4003, 5003 provides sufficient contact between the ball 4009, 5009 and seat 4003, 5003 to effect sealing. Increasing the load on the ball due to a pressure differential may slightly deform the ball 4009, 5009 in a spherical seat 4003, 5003, thereby enhancing sealing. Thus, since the radial clearance between the outer diameter of the ball 4009, 5009 and seat 4003, 5003 small, in some embodiments, to ensure full contact with the seat surface 4015, 5015 ball seat 4003, 5003, the ball 4009, 5009, it may be necessary to deform only to a small number.

[00113] the profile of the Seating surface 4015, 5015, as described previously, provides increased contact surface between the adjacent ball 4009, 5009 and the seat surface 4015, 5015. This contact surface provides an additional bearing surface for the ball 4009, 5009, thus preventing the destruction of the material of the ball due to compressive stresses that p is avishay the maximum allowable compressive stress of the material. If the differential pressure increases, the ball 4009, 5009 may deform and contact with the ball seat 4003, 5003, as described earlier, for additional support seat 4003, 5003. Due to the small radial clearance between the ball 4009, 5009 and profile 4015, 5015 Seating surfaces, deformation of the ball 4009, 5009 may be minimal.

[00114] In the calculation of the geometry and size of the ball seat 4003, 5003 to ensure appropriate initial landing of the ball 4009, 5009 and to provide sufficient bearing surface or support compressive loads on the ball 4009, 5009, which exceeds the tensile strength of the material of the ball, selects the appropriate compensation (i.e. radial distance) between the diameter of the seat 4003, 5003, and the outer diameter of the ball 4009, 5009. If radial clearance is too small, the initial landing of the ball in order to provide adequate sealing may be hindered. If radial clearance is too large, the ball 4009, 5009 may break down due to lack of support, when to the ball 4009, 5009 attached compressive load (i.e., pressure drop), which exceeds the tensile strength of the material world. In some embodiments, the radial distance between the diameter of the seat 4003, 5003, and the outer diameter of the ball 4009, 5009 may be in the range of about 0-5% of the radius of the ball 4009, 5009. More specifically, in some embodiments, the radial distance between what emetrol seat 4003, 5003 and the outer diameter of the ball 4009, 5009 may be in the range of about 0-2% of the radius of the ball 4009, 5009. The specialist will be clear that the determination of the radial gap may depend on factors including, inter alia, the radius of the ball, the material properties of the ball and the conditions of the well.

[00115] the Insulating device includes a ball seat 4003, 5003 and the ball 4009, 5009, made in accordance with the variants of the invention may provide a tube rupture, which can effectively seal and isolate the production zone and to withstand high temperature and pressure. Tube rupture, supplied by an isolating device in accordance with the disclosed here options were tested and it was found that supported sealing at pressures up to 15,000 psi at 400°F.

[00116] the production zone can be isolated using tube rupture, formed in accordance with the variants of the invention. Tube rupture, are supplied with an insulation device includes a ball seat with a profile that matches the profile of the ball, according to the disclosed here variants, is lowered through the borehole. The ball can be "captured" or is located inside the tube rupture and down well with tube rupture. As detailed previously, the plug gap is set at the place above the zone, Podles the overall sealing. Fluid produced lower tube rupture, can flow freely through the tube rupture. However, when exerting pressure drop, for example, when fluid flows from the surface into the reservoir to rupture zone over tube rupture, a ball mounted in the tube rupture (or ball lowered from the surface into the fluid flow), adjacent to the ball seat having a profile corresponding or substantially corresponding to the profile of the ball. Adjacent ball provides a seal between the zones above the tube rupture and under it, so that fluid pumped from the surface, can not enter the area under the tube rupture. In one embodiment, the contact surface of the ball in contact with the landing profile ball seat may be between 1/64 and 1/4 of the total surface area of the ball. In addition, in one embodiment, when the ball initially adjacent to the ball seat, the initial contact surface of the ball in contact with the landing profile ball seat may be between 1/32 and 1/4 of the total surface area of the ball. In other embodiments, the initial contact surface of the ball in contact with the landing profile ball seat may be between 1/16 and 1/8 of the total surface area of the ball.

[00117] If the load on the ball increases due to the increase of the pressure drop in zairoises device, the ball can be slightly deformed in a spherical seat. Because the profile of the ball seat corresponds to the profile of the ball and because the radial clearance between the ball seat and the ball is small, the ball is deformed only by a small amount until it is in contact with the ball seat. The contact area between the respective profiles of the ball seat and the ball provides an additional bearing surface for the ball, which can prevent or reduce the violation of the material of the ball due to compressive stresses. If you have exceeded the maximum allowable compressive stress for the material of the ball, the isolation device can support tightness thanks to the support of the corresponding profile of the landing surface of the ball seat. In addition, even at high temperatures, when the mechanical properties of the material of the ball may deteriorate the insulating device can maintain tightness thanks to the support of the corresponding profile of the landing surface of the ball seat. Thus, at high temperature and high pressure drop across the seal ball seat tube rupture, equipped with an isolating device, in accordance with the disclosed here options can provide an effective sealing areas on the tube rupture and under it.

[00118] In conventional ball seat shown in Fig. 1B, the radial is th the clearance between the outer diameter of the ball 38 and the inner diameter of the ball seat 36 is large. If a ball in the usual insulating device is loaded to high loads, the ball cannot be deformed sufficiently to contact with the seat surface 40. Therefore, the ball seat 36 is unable to provide adequate bearing surface for the ball 38. Without an appropriate support surface, the material of the ball is subjected to high compressive loads that may exceed the limits of the material world. As a result of this Orb will be destroyed, and the integrity to be lost. In addition, at high temperatures the mechanical properties of the material of the ball 38 may deteriorate. As usual ball seat inherent lack of support surfaces, the ball 38 is likely to deteriorate, for example, be squeezed out through the ball seat 36 or crack, thus losing tightness.

[00119] Mainly disclosed here can provide the ability to tube gap to withstand high pressure and high temperature environment. Tube rupture, equipped with an isolating device, in accordance with the disclosed here options can withstand temperatures of 350°F or higher and a pressure of 10,000 psi or higher. In some embodiments, tube rupture, equipped with an isolating device, in accordance with the disclosed here options can withstand the temperatures to 400°F and a pressure of 15,000 pounds per square the inch. In addition, the insulating device for tube rupture, disclosed here options, provides the geometry of the saddle, which corresponds to the profile of the ball, with a small radial clearance between the ball and ball seat, thereby limiting the total deviation or deformation of the ball at high pressure caused by stress. Thus, the isolation device in accordance with the disclosed here options can provide a hermetic seal for high pressure with a corresponding support surface of the load.

[00120] Although the invention is described with reference to a limited number of options, expert it is clear that they can be designed in other ways in the scope of the invention defined by only the supplied formula.

1. Insulating device for tube rupture, containing a ball seat having a landing surface, and the ball is made with the possibility of contact with the landing surface, and the profile of the landing surface is dome-shaped, with the first part of the profile has a radius of curvature that matches the radius of curvature of the profile of the balloon, and the second part has a radius of curvature greater than the radius of curvature of the first part.

2. Isolation device under item 1, in which the profile of the Seating surface contains at least two separate plot.

3. And airwomen device under item 2, in which at least one separate area contains a linear profile.

4. The isolating device according to p. 3, in which the angle of the first separate portion relative to the Central axis of the ball seat is different from the second angle of a separate section.

5. The isolating device according to p. 2, in which the ball seat further comprises a first section located on an axis above the landing surface and containing a cone-shaped profile.

6. Isolation device under item 1, in which balloon contains a phenol-aldehyde resin and fiberglass.

7. Isolation device under item 1, in which the ball seat is made from aluminium.

8. Tube rupture containing a mandrel having an upper end and a lower end, the seal element located around a mandrel, and a ball seat located in the Central channel of the mandrel and containing the landing surface having a non-linear profile, and at least part of the non-linear profile contains a number of separate linear sections, with each linear section has a different angle relative to the longitudinal axis of the mandrel.

9. Tube rupture under item 8, in which a part of the Seating surface includes a dome-shaped profile.

10. The method of isolation zones of the reservoir, containing the following stages: the descent tube rupture in the well to definitely the on position between the first area and the second area; installation of tube gap between the first area and the second area; placing a ball in the tube rupture; and the landing of the ball in the ball seat tube rupture containing the landing surface having a profile, and the first part of the profile has a radius of curvature essentially coincident with the profile of the balloon, and the second part of the profile has a radius of curvature different from the radius of curvature of the first part.

11. The method according to p. 10, further containing a higher pressure drop on the ball and ball seat.



 

Same patents:

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Valve for liquid // 2117203

FIELD: mining.

SUBSTANCE: group of inventions relates to mining industry and can be used in bottom-hole valve systems. The system includes a tubular column and a hollow activation ball. The tubular column is adapted for arrangement in a well and includes a seat. The activation ball is adapted for lowering to the well to be arranged in the seat. The ball includes an outer cover that forms a spherical surface. The outer cover forms a closed volume and is made from metallic material. The activation ball includes a supporting structure located on the inner surface of the outer cover.

EFFECT: improvement of efficiency of a bottom-hole tool activation system.

26 cl, 13 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: valve comprises hollow body with coupling and union threaded ends for coupling with flow string and with radial hole, hollow slide valve with radial bore and piston. Hollow slide valve is arranged off centre relative to said body and rigidly fixed at its outer surface. Radial bores of the body and slide valve are intercommunicated, hollow slide valve being provided with lateral channel. Piston is rigidly secured at rod lower part while rod upper part is provided with outer circular ledge and fitted tightly in adjusting nut for axial displacement relative to adjusting nut. Adjusting nut is screwed in hollow slide inner thread made at its top end. The piston is spring loaded downward from said nut. Fluid chamber communicated with the body inner space is made in said slide valve. Overpressure in said fluid chamber makes piston displace axially upward to communicate said chamber with the well casing annulus via the slide valve lateral channel.

EFFECT: decreased and controlled hydraulic pressure, ease of logging instrument arrangement, combination of several jobs in one lowering of tubing.

1 dwg

Cut-off valve // 2533394

FIELD: oil and gas industry.

SUBSTANCE: cut-off valve is installed in the tubing string over the hydraulic device and consists of a split casing with a hollow plunger is installed in its axial channel with a collar supported by a spring. In the axial channel of the hollow plunger there is a thrust with a bushing installed on it; the bushing has radial openings alternated with axial openings connecting cavity under the hollow plunger over the saddle. In the axial channel there is a bushing with a hollow tube equipped with a disc valve at the end pressed to the saddle by the spring. Between the hollow plunger and the split casing there is a circular chamber coupled hydraulically by a radial opening to the axial channel of the bushing and hollow tube. In the bushing there is a bottom with the central axial channel where a bypass valve is installed with a retainer covering bypass openings in the bottom in initial position and its stroke is limited from bellow by a locking ring.

EFFECT: sealing of the tubing string axial channel from the well cavity at any depth of the well and impact of hydrostatic pressure to the disc valve, filling of the tubing string axial channel by formation fluid at the device running in to the well, opening of the disc valve at excess pressure generation in the axial channel of the tubing string with free passage of hydraulic fluid to the device placed below.

2 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention can be used for pulse injection of fluid into bed. Proposed device comprises case, concentric pipe with central channel arranged therein, openings, nuts and spring. Said nut is fitted on pipe outer surface at its top while spring if arranged between nut and case with inner cylindrical recess. Radial channel are made in lower part of the case cylindrical recess. Note here that hollow cylindrical valve equipped with circular ledge is fitted rigidly to the pipe fitted in the case to perform limited sealed displacement downward relative to inner cylindrical recess of the case. Case cylindrical recess above cylindrical valve circular ledge communicates via openings with central channel while inner cylindrical recess cavity above said ledge communicates via radial channels with the space outside the case. Besides, it has replaceable bush and stiff centring skid with stripping valve arranged atop said pipe. In compliance with this invention, hollow cylindrical valve below the case cylindrical recess is equipped with radial openings. Radial holes tightly stopped from inside by replaceable bush are arranged below radial openings in hollow cylindrical valve. From top, said replaceable bush is connected with the case by rod fitted in radial holes of said valve. Note here that hollow cylindrical valve is plugged from bottom while said case can perform restricted axial reciprocation along with replaceable bush relative to said valve at forcing the fluid in this device.

EFFECT: higher fluid flow rate at pulsed injection.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: group of inventions is related to mining engineering and may be used for hydraulic fracturing of hydrocarbon formation. The downhole system comprises a variety of slip couplings having the central end-to-end channel. At that each of the slip couplings may be actuated by a single ball. Each slip coupling has a movable insert, which, depending on its position, may either block or provide radial flow of the fluid between the inner and outer parts of the coupling. The insert is shaped from the inner side of the movable insert thus ensuring connection of the pusher with insert and movement of the insert, which prevents passage of the fluid to inner part of the slip coupling.

EFFECT: improvement of hydraulic fracturing efficiency for several formations next by one wellbore.

21 cl, 11 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes a separate running in to the well of a pipe string with packer system, sensor units (when required) to control parameters of the well state, a pilot-controlled electrical or electromechanic valve and downhole wet contact unit connected and disconnected electrically and mechanically. The pilot-controlled electrical valve is intended for opening/closure for delivery of the formation fluid to overpacker area of the well. A separate running in is made for the pipe string in the lower part of the downhole wet contact unit connected and disconnected electrically and mechanically by an electrical line ensuring data transfer from monitoring sensors, supply and transfer of commands to the pilot-controlled electrical or electromechanic valve from the ground station or running in is made for the pipe string equipped with a deep well pump, electric submersion pump or a shank of any other type fixed in the lower part of the pump equipment, or a telemetry unit located under the pumping unit, the upper part of the downhole wet contact unit connected and disconnected electrically and mechanically. The electrical line may be connected at the wellhead by a separate cable line when submersible electric drive (sucker rod pump, free-flow production method, etc.) is not used in the downhole equipment or in composition with the fourth core of the submersible cable for electric pumps up to an electric drive of the pump equipment and then by a separate cable or from the zero point of the submersible motor or from telemetric system of the submersible motor. The shank may be equipped with emergency isolation device. Upon matching of the upper and lower part of the downhole wet contact unit connected and disconnected electrically and mechanically the electrical coupling between the ground station for the formation operational parameters and the pilot-controlled valve is set and in result there is a option to control and measure parameters of the well state and to cut off the formation fluid when maintenance and repair operations are performed for the pumping equipment.

EFFECT: option to perform lifting of the pumping equipment for maintenance and repair without well kill operations.

7 dwg

Universal valve // 2528474

FIELD: oil-and-gas industry.

SUBSTANCE: proposed valve comprises valve unit arranged in hollow cylindrical body cushioned by threaded sleeve, shutoff ball arranged in valve unit groove, seat, spring and thrust with through holes. Thrust spherical end is located at initial position with guaranteed clearance relative to said ball. Blind lengthwise groove arranged regularly in circle are made in valve unit body wall. Two collars are made at valve body outer cylindrical surface and have circular grooves to receive split sleeves. The latter are arranged so that clearance exists between valve body central bores surface and body outer cylindrical surface. Circular groove for seals is made at threaded sleeve central through axial bore surface. Said seals are composed of two components, i.e. resilient element and two stiff split bearing rings. Working fluid passage with outlet is made inside aforesaid thrust. Spring is pre-compressed by force defined by working pressure and arranged in sealed chamber.

EFFECT: reliable, stable and efficient operation of valve and pump.

5 cl, 8 dwg

FIELD: oil and gas industry.

SUBSTANCE: cut-off system includes equipment of the well with at least one packer with or without return valve downstream connected to the cut-off landing nipple directly or through one or several tubes, and running in and out of an electric submersible pump unit at the pipe string. At that the cut-off valve consist of a lock, a case with input and output passing channels, sealing collars, a controlled element and a locking group. According to the invention the system is equipped with a hollow shank interconnected hydraulically from bellow to the cut-off controllable element and to the cavity of the pipe string over the electric submersible pump unit from the above. For this purpose the pipe string and hollow shank upstream and downstream the electric submersible pump unit are equipped respectively with axial and off-centre upper and lower couplings with taps interconnected by a hydraulic channel passing close to the electric submersible pump unit. At that the upper coupling has either a through axial channel or a through off-centre channel or a through axial landing channel. When the upper coupling is made with the landing axial channel then a divider for two cavities is run in at the additional pipe string of a less diameter with a side return valve. The lower coupling is connected hydraulically to remote measuring equipment. Besides the hollow shank with or without crossover unit is equipped with a disconnector with a running tool or without it. At that the cut-off valve is either run in to the well or set to the landing nipple before running in of the electric submersible pump unit or run in to the well at the running tool under the hollow shank and placed to the landing nipple. At that the disconnector under the hollow shank is connected to the disconnector or its controlled element or the landing nipple. The cut-off valve with a lock is equipped by a pressure adjuster and its sealing collars are set either lower or upper than the output passing channel. The case and controlled element of the cut-off valve form a working chamber connected through the hollow shank and hydraulic channel to the cavity of the pipe string or additional pipe string over the electric submersible pump unit. The controlled element is made as a piston or plunger or bellows capable of the locking group opening and closing at start-up and shutdown of the electric submersible pump unit or at the target generation or release of excess pressure in the additional pipe string or the pipe string. The closing group is made as a support saddle assembly and a gate or as a cylinder and a plunger gate. The piston or bellows or the gate is spring-loaded under the preset force. The cut-off valve is made with or without control mechanism to fix position of the controlled element rotated at the rod or in a case of a coded bushing with through or blind cam slots designed for the limiter in the case or at the rod respectively.

EFFECT: improving operational efficiency of the pumping well due to prevention of the productive stratum bullheading downstream the packer at replacement of the electric submersible pump unit.

3 cl, 21 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: set of inventions relates to production of hydrocarbons, particularly, to activation of multiple borehole devices for creation of multiple extraction zones. Method of selective activation includes several steps. At first step, combination of coded magnets is defined so that every valve sleeve in well working area includes set of magnets to be attracted to individual set of magnets at activating dart. Then, valves are opened in the selected order defined by individual dart pump feed into well shaft. Proposed mechanism comprises valve with sleeve suitable for displacement between open and normally closed positions, set of valve magnets and dart to be fed by pump in borehole shaft. Set of magnets is arranged an said sleeve. Said dart comprises set of dart magnets coupled with set of valve magnets so that said dart is connected with said valve at location there nearby while sleeve displaces from closed position to open position.

EFFECT: higher efficiency of extraction.

20 cl, 13 dwg

FIELD: mining.

SUBSTANCE: invention relates to mining and can be used in downhole valve systems. Method of control over valve operation can include fitting the electric drive in flow channel extending over valve length and control over shutoff device by feeding electric power to said drive. External safety valve can include shutoff device that selectively allows and shuts off fluid flow through said lengthwise flow channel. At least one connector can be connected to plug-in safety valve fitted at appropriate position in flow channel. Method of control over valve in downhole can comprises fitting of plug-in safety valve in said external safety valve and executing the control over said plug-in safety valve by electric current fed from external safety valve to said plug-in safety valve.

EFFECT: higher reliability.

23 cl, 9 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: valve has body of steel, throttling assembly, locking assembly with ball and saddle for it. Between locking and throttling assemblies resilient impenetrable wall separating these is mounted fixedly with possible interconnection via U-shaped, turned by its knee upwards, tubular channel, with inner diameter greater than ball diameter, having two branches directed downwards and having various lengths. Elongated pipe branch is connected through open end fixedly placed on wall to hollow of body throttling assembly. Short branch end is placed above wall and is within hollow of locking assembly. Short branch pipe is extended above the knee for distance greater than ball diameter. It is made in form of branch pipe with closed upper end, forming a hollow - tank with stopping device for placement and holding of ball therein in starting position. Ball can possibly fall freely under its own wait in downward direction onto saddle if released by stop as a result of effect from outside force from cementing plug at the end of cementation.

EFFECT: higher reliability, better quality.

7 cl, 8 dwg

Well valve device // 2250353

FIELD: oil and gas industry.

SUBSTANCE: well valve device has body with upper inner and lower outer attaching threads. In recess, made in middle portion of body, a lid is fixedly placed with through aperture. In lower portion of body from the end of recess side and longitudinal channels are made, provided with saddles and ball valve with diameter d, mounted in saddle of side channel and capable of returning through recess into longitudinal channel and backwards. On the saddle of longitudinal channel ball valve with diameter D is placed. Diameter D is greater than diameter d of side channel ball valve. Distance L between centers of side and longitudinal channels is not greater than two diameters d of ball valve of side channel, i.e. L < 2 d. Depth G of placement of mounting surface of longitudinal channel saddle from end of recess is greater than sum of diameters d and D of ball valves, i.e. G < D + d. Depth g of placement of mounting surface of side channel saddle surface from end of recess is not greater than half of diameter d of ball valve of side channel, i.e. g < 0.5 d. on end surface of lid, directed to channels in diametric plane, a small recess is made in form of cylindrical segment having width B and height H. Width B of small recess is greater than diameter d of ball valve of side channel and is less than diameter D of ball valve of longitudinal channel, i.e. d < B < D. Height H of small recess is greater than diameter d of ball valve of side channel, i.e. H > d. Symmetry plane of recess coincides with plane, passing through centers of longitudinal and side channels. Through aperture of lid is made above small recess in form of groove with width b, value of which is less than diameter d of side channel ball valve, i.e. b < d. Most of area of through aperture is made above half of small recess, placed above longitudinal channel.

EFFECT: higher reliability, broader range of functional capabilities, lesser manufacture and maintenance costs.

8 dwg

FIELD: oil and gas industry.

SUBSTANCE: device has body, and differential plunger with holder and compacting elements, saddle, spreader bushing and spring-loaded clamp on axis, mounted therein. Body is made with its possible connection to lower portion of product column. Spreader bushing is made eccentric and is mounted in eccentric recess. Clamp is provided with several springs. Differential plunger is connected to holding sleeve. Sleeve is made with possible interaction with holder being part of assembly of lower portion of drilling column. Holder controls closing of cut valve after letting chisel into plunger. Sleeve is mounted at distance from clamp, greater, than length of face engine, chisel and holder.

EFFECT: higher reliability and safety.

2 dwg

FIELD: oil industry.

SUBSTANCE: valve has limiter with saddle and side channels, check valve, placed at lower portion, bushing, mounted in axial channel of limiter at shear elements above side channels with possible hermetic overlapping thereof. According to invention limiter is additionally equipped with stop, interacting with bushing in its lower position. Outer surface of limiter is provided with elastic ring with stop above side channels, and made with possible hermetic mounting of limiter in required range between casing string pipes during assembling thereof. Saddle is made with cylindrical piece at lower plane of limiter. Check valve is made plated, spring-loaded with possible rotation relatively to fixture to limiter. The latter consists of rigidly interconnected elastic collar, localizer and cylindrical plate. On the latter ring-shaped recess is made, mounted oppositely to inner lower plane of limiter. Outer plane of cylindrical plate is positioned oppositely to limiter saddle. Elastic collar is placed between lower plane of limiter and cylindrical plate.

EFFECT: higher reliability, simplified manufacture and maintenance.

1 dwg

FIELD: oil production industry, particularly to regulate and/or measure flow parameters.

SUBSTANCE: regulator comprises body with outer groove, side pass channels and axial connecting channel, lower and upper collar holders with outer packing members, fishing head and tail piece with fixer. Fishing head has side pass channels and/or through axial connecting channel. The body or lower and upper collar holders and/or fishing head and/or tail piece have inner landing seats for receiving locks or have borings. Removable restrictors are installed at least in two borings and have opposite direction. The restrictors have equal or different pass and/or outer diameters and may have free or spring-loaded back valves performing restricted movement. Summary flow area of removable restrictors is less than that of side pass channels of the body.

EFFECT: increased efficiency of output and/or pressure well formation operation due to increased regulator cross-section along with limited size thereof, extended range or pressure and flow regulation during fluid extraction and/or working substance pumping-in.

18 cl, 9 dwg

FIELD: oil well operation, particularly to supply power and communication signals to downhole device.

SUBSTANCE: oil well has borehole with pipe structure arranged inside the borehole, communication system performing transmission of time-varying signal along pipe structure, as well as hydraulic system electrically linked with pipe structure and adapted to be connected to downhole device, to receive power and to control downhole device. Communication system also has impedance device arranged around pipe structure to form conductive section in which signal interference is provided, wherein the signal is current. To operate downhole device working liquid pressure is increased with the use of current. Hydraulic drive system comprises electric drive for above signal receiving, which activates pump to increase working liquid pressure. Connected to pump is drive actuated by working liquid and connected to downhole device in its working position to operate the downhole device. Signal may include communication signal to selectively operate downhole device, particularly valve.

EFFECT: decreased electric power losses during signal transmission to downhole device.

26 cl, 6 dwg

FIELD: hydrocarbon (oil, gas, gas condensate, gas-hydrate or mixture) production and formation pressure maintaining means in multiplay fields and, particularly, for simultaneous separate, as well for periodical or successive operation of several production facilities (production formations or interlayers) by single (blower, gas-lift, beam, injection and so on) boreholes.

SUBSTANCE: plant comprises one or several pipe strings lowered and installed in borehole. At least one pipe string is provided with at least two devices, namely with packer and disconnector. The plant may be separated from packer and removed from the borehole after lowering and leak-proof fitting of at least one packer in pipe string. Then pipe string having lesser, equal or greater diameter and provided with one or several devices, namely packer, disconnector, may be lowered and installed in the borehole. The disconnector comprises two removable and fixed parts, one or several borehole chambers with releasable valves, telescopic connection and pump. Pipe string is lowered directly in the borehole or in pipe string having greater diameter or is connected in leak-proof manner but loosely with corresponding fixed packer through disconnector. Pipe string bottom below packer installed above or under lower formation is hydraulically isolated or connected with borehole bottom.

EFFECT: increased technological efficiency and plant reliability.

23 cl, 38 dwg

FIELD: gas lift oil wells for reservoir fluid development and methods of reservoir gas usage for production thereof, as well as electronically operated downhole valve.

SUBSTANCE: well comprises production string extending inside well through oil-bearing and gas-bearing zones and electrically operated downhole valve. The valve is connected with production string and adapted to regulate high-pressure trip gas flow. Well is provided with connection means, which supplies gas from gas-bearing zone in downhole valve, inductive throttle arranged around production string near downhole valve to transmit electric power and control signals by production string to downhole valve through the first and the second outputs. The outputs are linked with production string from power source side and from return circuit side of inductive throttle correspondingly. Method for above well operation is also disclosed.

EFFECT: increased efficiency and operational reliability.

24 cl, 5 dwg

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