• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    EDANTE RING ON A ROTARY CONTROL DEVICE. An annular seal having a sealing member and method of use is provided to seal an oilfield equipment item. The ring seal has an inner diameter to receive the item of oilfield equipment and a frame. The sealing member 6 is contiguous with the frame. The ring seal 6 is configured for durability, insofar as it resists wear, inversion, increases lubrication capacity, allows tightening and / or otherwise generally increases strength, toughness, and / or permanence.
    公开号:BR112014016321B1
    申请号:R112014016321-9
    申请日:2012-12-28
    公开日:2020-11-17
    发明作者:Don M. Hannegan；James Chambers；Melvin Jacobs
    申请人:Weatherford Technology Holdings, Llc；
    IPC主号:
    专利说明:

    TECHNICAL FIELD
    [001] This disclosure refers to sealing members used in oil field and borehole operations. FUNDAMENTALS
    [002] Oilfield operations can be carried out in order to extract fluids from the earth. When a well site is completed, pressure control equipment can be placed close to the earth's surface. The pressure control equipment can control the pressure in the well hole during drilling, completion and production of the well hole. Pressure control equipment can include burst prevention (BOP), rotary control devices, and so on.
    [003] The rotary control device or RCD is a drilling device with a rotation seal that contacts and seals against the drill string (drill tube with tool joints, casing, drill collars, Kelly, etc.) for purposes pressure control or fluid flow to the surface. For reference to an existing description of a rotary control device, see patent publication number 2009/0139724, entitled "Lock Position Indicator System and Method", patent publication number 2011/0024195, entitled "Drilling with an RCD High Pressure ", US patent publication 2011/0315404 entitled" Lubricant seal for use with a tubular ", US patent number 8,100,189, US patent number 8,066,062, US patent number 7,240,727, US patent number 7,237. 618, US Patent 7,174,956, US Patent 5,647,444, US Patent 5,662,181, and US Patent 5,901,964, the disclosures of which are hereby incorporated by reference. The seals on the RCD are typically constructed of an elastomeric material and have a tendency to wear out with use. The higher the differential pressure through the ring seal, the faster the wear speed. In addition, the seals tend to invert during pulling out from the RCD, a drilling operation referred to as "suppress". The seal can reverse by bending inward and bending pear inside itself. When the seal reverses it may fail to seal the well hole ring and needs to be replaced. In high pressure, and / or high temperature wells, the need is greater for a more robust and efficient seal to extend its useful life. In some applications or functions of a seal, there is a need to increase lubrication capacity and, consequently, reduce frictional heat that accelerates elastomer wear. In others, there is a need to increase the seal extension tension in the drill string, thereby ensuring the torque transfer required to rotate the inner stroke of the RCD bearing assembly in harmony with the drill string components being sealed against.
    [004] There is a need for an annular seal having improved strength, toughness and / or permanence in an RCD. SUMMARY
    [005] An annular seal having a sealing member and method of use are provided for sealing an item of oilfield equipment. The annular seal has an inside diameter for receiving the oilfield equipment item and a frame. The sealing member is adjacent to the frame. The ring seal is configured for durability, insofar as it resists wear, inversion, increases lubrication capacity, allows tightening capacity and / or otherwise generally increases strength, toughness, and / or permanence.
    [006] As used herein the terms "radial" and "radially" include directions inward towards (or outwardly away from) the central axial direction of the drill string or oilfield equipment item, but not limited to to directions perpendicular to that axial direction, or running directly through the center. Instead, such directions, while including perpendicular and towards (or away from) the center, also include those transverse and / or off-center still moving inward (or outward), through or against the surface of an outer sleeve. of oilfield equipment item to be hitched.
    [007] As used herein, the term "additive" generally refers to optimizers for material properties such as reducing the coefficient of friction, wear resistance, resistance to propagation and cracking, inducing self-healing, etc., and can include, but are not limited to, additives, granules, bags, formulations homogeneously added to a material and / or polymers and self-healing compounds (capsule-based, vascular, or intrinsic). Aramid fiber / pulp, molybdenum and wear-resistant granules are MM examples of "additives". BRIEF DESCRIPTION OF THE DRAWINGS
    [008] Figure 1 shows a schematic view of a well hole location. Figure 1A shows a schematic view of another embodiment of a well hole location. Figure 1B shows a schematic view of another embodiment of a well hole location. Figure 2A shows a cross-sectional view of a seal according to an embodiment. Figure 2B shows a cross-sectional view of the seal of Figure 2A according to an embodiment. Figure 2C shows a cross-sectional view of a portion of the seal of Figure 2 according to an embodiment. Figure 2D shows a cross-sectional view of a portion of the seal of Figure 2B according to an embodiment. Figure 3 shows a cross-sectional view of the seal in another embodiment. Figure 4 shows a cross-sectional view of the seal in another embodiment. Figure 5 shows a cross-sectional view of the seal in another embodiment. Figure 6 shows a cross-sectional view of the seal in another embodiment. Figure 7 shows a cross-sectional view of the seal in another embodiment. Figure 8 shows a cross-sectional view of the seal in another embodiment. Figure 9 shows a cross-sectional view of the seal in another embodiment. Figure 10 shows a cross-sectional view of the seal in another embodiment. Figure 11 shows a cross-sectional view of the seal in another embodiment. Figure 12 shows a cross-sectional view of the seal in another embodiment. Figure 13 shows a cross-sectional view of the seal in another embodiment. Figure 14 shows a cross-sectional view of the seal in another embodiment. Figure 14A shows a cross-sectional view of another embodiment of a seal similar to the embodiment of Figure 14. Figure 15 shows a cross-sectional view of the seal in another embodiment. Figure 16 shows a cross-sectional view of the seal in another embodiment. Figure 16A shows a cross-sectional view of the seal in another embodiment. Figure 17A shows a side view of the seal in another embodiment. Figure 17B shows a cross-sectional view of the seal in the embodiment of Figure 17A. Figure 18 shows a cross-sectional view of the seal in another embodiment. Figure 19A shows a cross-sectional view of the seal in another embodiment. a portion of the seal in the embodiment of Figure 19A. Figure 20A shows a cross-sectional view of the seal in another embodiment. Figure 20B shows a cross-sectional view of a portion of the seal in another embodiment related to Figure 20A. Figure 21 shows a cross-sectional view of the seal in another embodiment. Figure 22 shows a cross-sectional view of the seal in another embodiment. Figure 23 shows a cross-sectional view of the seal in another embodiment. Figure 24 shows a cross-sectional view of the seal in another embodiment. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT (S)
    [009] The description that follows includes exemplary apparatus, methods, techniques and instruction sequences that incorporate techniques of the inventive subject. However, it is understood that the modalities described can be practiced without these specific details.
    [010] Figures 1, 1A and 1B represent schematic views of examples of rig well locations offshore and onshore 100 (many applications are contemplated, and by way of example only, the described modalities are applicable for drilling rigs , such as self-elevating, semi-submersible, drilling ships, barge probes, rig probes, deep water probes and land probes) having a seal 102 to seal an item or piece of oilfield equipment 104. Well location 100 can have a well hole 106 formed in the land or seabed 110 and lined with an enclosure 108. On the surface of the land 110 (Figure 1) or seabed 110 (Figure IA), or above the riser 111 (Figure 1B ), one or more pressure control devices 112 can control the pressure in well bore 106. Pressure control devices 112 can include, but are not limited to, BOPs, RCDs, and the like. Seal 102 is shown and described here as being located on RCD 114. Seal 102 can be one or more ring seals 118 located within RCD 114. Seal 102 can be configured to fit and seal oilfield equipment during operations of oilfield. Seal 102 can have a number of variant configurations as will be discussed in more detail below. In one embodiment, the seal is a lower element, or lower seal, in a double design RCD 114. Oilfield equipment 104 can be any equipment suitable to be sealed by seal 102, including, but not limited to, a bushing , a bearing, a bearing assembly, a test plug, a damping adapter, a coupling sleeve, a sleeve, sealing members, a tubular, a drill pipe, a tool joint, and the like.
    [011] Seal 102 is configured for durability and can be configured to improve one or more aspects over traditional seals used in an RCD. Seal 102 may have a particular shape, or combination of materials that ensures better performance of seal 102, as will be discussed in more detail below. Seal 102 can rotate with oil field equipment 104 or remain stationary while oil field operations are performed. Seal 102 can be configured to increase lubricity, wear resistance, chemical compatibility, and temperature tolerance in an RCD sealing area. Seal 102 can be further configured to increase the friction of the seal area. Seal 102 may be suitable for an element whose primary function is to transfer torque to rotate oilfield equipment 104, for example, an interior stroke of the RCD. Seal 102 can have hydraulic or pneumatic power transmission with the PLC to ensure that oilfield equipment 104, the inner stroke, rotates in sync with the top drive or drill string. Seal 102 can be resistant to inversion when suppressing under high differential pressure.
    [012] Well location 100 can have a controller 120 to control equipment over well location 100. Controller 120, and / or additional controllers (not shown), can control and / or obtain information from any suitable system on well location 100 including, but not limited to, pressure control devices 112, RCD 114, one or more sensors (s) 119, a clamping apparatus 122, a rotating apparatus 124, and similar. The clamping device 122 can be a pair of grafts configured to secure a tubular 125 (such as a drill string, a production string, a casing and the like) to a probe floor 126; however, the clamping device 122 can be any suitable clamping device. As shown, the rotation apparatus 124 is a top drive to support and rotate the tubular 125, although it may be any suitable rotational device including, but not limited to, a Kelly, a tube die, and the like . Controller 120 can control any suitable equipment over well location 100, including, but not limited to, a draw works winch, displacement block, pumps, mud control devices, cementing tools, drilling tools, and so on.
    [013] Figure 2A shows a cross-sectional view of seal 102a in one embodiment. Seal 102a can be configured to be pre-tensioned by one or more springs 200 cured in a sealing material 202. Sealing material 202 can be any suitable sealing material, or combination of materials, for sealing field equipment. petroleum 104 (as shown in Figure 1), including, but not limited to, rubber, an elastomeric material, a polymer, a plastic material, a ceramic, a metal of any combination thereof, and the like. As shown in Figure 2A, the seal 102a is in the static, or not forced, position. The springs 200, as shown, are leaf springs coupled to a top ring 204 and a bottom ring 206. The top ring or frame 204 and bottom ring or frame 206 can be circular plates configured to support the springs 200, or have any other suitable design. Although springs 200 are shown as leaf springs, springs can be any suitable pressure element, including, but not limited to, tension bars, bending bars, spring steel, reinforced composite plastic, spiral springs, and similar.
    [014] In the static position, the springs 200 can be in an upright position, or simply the natural position of the spring 200. The sealing material 202 can then be molded around the springs 200. Initially, the inside diameter 208 of the sealing material 202 may be greater than the outside diameter of oilfield equipment 104, or such as the tool gasket. The seal 102a can then be put into rotation tension before the curing of the sealing material 202. The rotation tension can be created by rotating at least one of the top ring 204 and / or the bottom ring 206 with respect to one to the other. Seal 102a is left in rotation until seal material 202 has cured. The rotating force can then be released.
    [015] Figure 2B shows a cross-sectional view of the seal 102a after the rotational force has been released and after the seal material 202 is cured. Releasing the rotational force can compress the sealing material 202. Compression of the sealing material 202 can force a portion of the sealing material to invade the inner diameter, thereby reducing the inner diameter 208 of the seal 102a. Sealing area 210 can be formed within seal 102a which is configured to engage oil field equipment 104 during oil field operations. The reduced inside diameter 208, as shown in Figure 2B, may be smaller than the outside diameter of oilfield equipment 104, or tool gasket. As oil field equipment 104 is moved through seal 102a, one or more springs 200 may allow seal material 202 to automatically adjust to the size of oil field equipment 104. Automatic regulation can reduce material wear seal 202, thereby increasing seal life 102a. The automatic adjustment can also allow a faster elastic recovery time of the sealing material 202.
    [016] Figure 2C shows the top ring 204, the bottom ring 206, and one or more springs 200 without the sealing material 202 in the static state. As shown, there are several vertical springs 200 that couple rings 204 and 206. In the static state, one or more springs 200 can be linear without force stored in one or more springs 200.
    [017] Figure 2D shows the top ring 204, the bottom ring 206, and one or more springs 200 without the sealing material 202 in a position with rotation tension applied to the top ring 204 and / or the ring bottom 206. As shown, one or more springs 200 can deform and store energy within one or more springs 200.
    [018] Figure 3 describes seal 102b in an alternative embodiment. Seal 102b may have a frame 300 (more commonly called a mounting ring), a sealing member 302a, a sealing surface 304 and one or more additives 306 incorporated into the sealing member 302a. Frame 300 can be configured to couple seal member 302a to a portion of RCD 114, for example, a bearing assembly (not shown). Frame 300 can be constructed of any suitable material, including, but not limited to, a metal, a ceramic, a compound and the like. The frame 300 can have one or more fasteners 308 configured to couple the frame 300 to the sealing member 302a.
    [019] The sealing member 302a as shown has a substantially frustroconic shape of the outer surface 310 and the inner surface 312. The inner frustroconic surface 312 can assist in orienting oilfield equipment 104 (as shown in Figure 1) towards sealing surface 304 during execution. Sealing surface 304 can be configured to engage the outside diameter of oilfield equipment 104. Sealing member 302a can be made of any sealing material, including those described herein. The sealing member 302a can be molded or cast with any volume or number of additives 306 in the sealing member 302a.
    [020] Additives 306 can be pelleted aramid pulp in one embodiment. Additives 306 can be attached to sealing member 302a using any suitable method, including, but not limited to, phenolic technology, and the like. The additives can be in the form of crystalline spheres, or BBs, in one embodiment, although the 306 additives can have any suitable shape. In one example, but not limited to, additives 306 may comprise two percent or less of the volume of material in the nose 307 of the sealing member 302a in one embodiment. In addition, additives 306 may comprise any suitable amount of nose volume 307 of sealing member 302a. Additives 306 can add elasticity by allowing sealing member 302a to stretch or stretch more than it would without additives 306. This can assist sealing member 302a in sealing oilfield equipment 104 more flexibly, thereby reducing wear on the sealing member 302a during operations. Additives 306 can reduce the stress and deformation on the sealing member 302a during the service life of the sealing member 302a. Additives 306 can be any material suitable for reducing the stress on the sealing member 302a. In one embodiment, additives 306 are constructed from any of the materials found in U.S. Patent No. 5,901,964 which is incorporated herein by reference in its entirety.
    [021] Figure 4 represents the seal 102c in an alternative embodiment. Seal 102c may have frame 300a, seal member 302a, seal surface 304a similar to seal surface 304 described in Figure 3. Seal 102c may have one or more high compressive strength additives 400 molded in one region specific target, which in the embodiment shown is the sealing area 402, of the sealing member 302a. Additives 400 can be molded, or bonded, to the sealing member 302a in any suitable manner. Additives can also serve to reduce frictional heat, which is detrimental to the 402 base material. Sealing member 302a can be any suitable sealing material, including those described herein. Additives 400 can be any suitable material optimizer including, but not limited to, ceramic, nylon, beryllium chips, hydraulic fracture propellants, and the like. Additives 400 can have any suitable shape, including, but not limited to, spherical, irregular, globular shape, crystalline BB shape, rough surface BBs, and the like. Additives 400 can be configured to reduce the wear of the sealing material during operations. Additives 400 may include an additive, or be made of a material to specifically target the improvement of strength and wear of the sealing member 302a, for example, additives 400 may be of a material attractant to a magnet, such as example, a propellant processed from bauxite or hydroxides / oxides of iron and aluminum. During manufacture, desired regions of the mold may include a magnet or magnetic field to concentrate the additives 400 immediately after the mixture is poured (into the mold) in a desired region of the sealing member 302a.
    [022] For reference to an existing description of a 306 or 400 additive in the specific embodiments of a polymer and / or self-curing compound (based on capsule, vascular, or intrinsic), see Patent Publication No. US 2011/0003137, entitled "Composite laminate with self-healing layer", patent publication No. US 2010/0075134, entitled "Interfacial functionalization for self-healing compounds", patent publication No. US 2008/0299391, entitled "Capsules, methods for making capsules, and compounds including self-healing ", Patent Publication No. EP EP2285563 entitled" Composite laminate with self-healing layer ", and U.S. Patent No. 8,188,293 whose disclosures are hereby incorporated by reference.
    [023] Figure 5 describes the seal 102d in an alternative embodiment. Seal 102d can have a frame 300b, a sealing member 302b, and an inner support frame 500, or inner skeleton. The inner skeleton 500 can be slid over a manufacturing mandrel prior to compression molding 302b or casting a meltable elastomer, such as polyurethane. The frame 300b can act in a similar way as the frame 300a to support the sealing member 302b and couple to a portion of the RCD 114 (as shown in Figure 1). As shown, frame 300b can have fastener 308 configured to couple frame 300b to sealing member 302b. There may be an optional tension ring 502, or seal ring, configured to secure seal member 302b to frame 300b. The support frame 500 can increase the stiffness of the sealing member 302b during the service life of the sealing member 302b. Increased rigidity can prevent seal member 302b from reversing during oil field operation as a suppression. The sealing member 302b may include a frustroconic outer surface 310b and a frustroconic inner surface 312b. In addition, sealing member 302b can have sealing surface 304b configured to engage and seal oil field equipment 104 (as shown in Figure 1) during oil field operations.
    [024] The inner support frame 500 can extend from frame 300b to the sealing surface 304b in one embodiment. In this embodiment, the inner support frame 500 can be configured to avoid reversing the sealing member 302b. In another embodiment, the inner support frame 500 may extend from a location close to the frame 300b to a location past the sealing surface 304b. In this embodiment, the inner support frame 500 can be configured to prevent inversion and reduce wear on the sealing member 302b during oil field operations. The inner support frame 500 can be constructed of any suitable material, including, but not limited to, an aramid rope, a rope, a loosely woven aramid rope that will allow the rope to stretch when the sealing member 302b is stretched , a metallic material, a ceramic, a polymer and, in elastic material, and the like. The inner support frame 500 may consist of vertical filaments or members, helical filaments, any combination thereof, and the like.
    [025] Figure 6 illustrates seal 102e in another alternative embodiment. Seal 102e may have frame 300c, sealing member 302c, and one or more inserts 600 coupled to the inner surface of sealing surface 304c. The sealing member 302c and the frame 300c can be configured in a similar manner as any of the sealing members 302 and frames 300 described herein. The one or more inserts 600 can be any material resistant to abrasion and / or appropriate wear that is inserted into the sealing surface 304c of the sealing member 302c. The inserts 600 can be arranged in any suitable way on the sealing surface 304c provided that the inserts 600 engage the oil field equipment 104 while the sealing member 302c seals the oil field equipment 104. For example, the inserts 600 can be vertical, horizontal, angled, transverse, spiral-shaped, or any combination thereof.
    [026] The inserts 600 can be continuous around the sealing surface 304c or be discontinuous. The one or more inserts 600 can be molded into the sealing member 302c. Once molded on the sealing member 302c, one or more inserts 600 can be milled, or cut, to match the inner diameter of the sealing surface 304c. One or more inserts can be constructed of any suitable material, including, but not limited to, a polyamide rope, formulations of zirconium, metal, sintered non-sparking ceramic (such as Al-bronze, copper-beryllium, and the like) ), acetal resins, and the like. If one or more inserts 600 are metallic, or hard, the one or more inserts 600 can be segmented so as to allow the sealing surface 304c to conform to oil field equipment in variant form 104 during sealing operations. The one or more inserts 600 may be spaced apart to allow the sealing member 302c to surround the sealing surface 304c to allow sufficient elongation of elastic material of the sealing member 302c between one or more inserts 600.
    [027] Any of the seals 102 described above, and / or below, can have a chemical application, or chemical treatment, for the sealing member 302. The chemical treatment can be configured to improve the life of the sealing member 302 during oil field operations. In one embodiment, the chemical treatment may be an application of SULFRON, a modified TWARON aramid, to seal member 302. SULFRON can improve the properties of cured peroxide and sulfur rubber compounds. Chemical treatment can reduce hysteresis, heat build-up and abrasion. Chemical treatment can improve the properties of flexibility, tearing and fatigue.
    [028] In another embodiment, the chemical treatment is a PROAID LCF additive applied to the sealing member 302. PROAID LCF is a lubricating additive in amounts of approximately five hundred of the amount of base material. The PROAID LCF can flourish, activate or rupture come to the surface of the sealing member 302 when abrasions on the sealing member 302 occur. This chemical treatment may be suitable for the bottom element, or seal 102, of a double element RCD 114.
    [029] Figure 7 shows the seal 102f in another alternative embodiment. Seal 102f can have frame 300d, seal member 302d, and a lubrication cavity 700. Frame 300d can be configured to couple seal member 302d to RCD 114 (as shown in Figure 1) in a similar manner to that previously described. The frame 300d and the sealing member 302d can have the lubrication cavity 700 through them in order to supply a volume of lubricant (represented by the arrow 702) to the sealing surface 304D. Lubricant 702 can be any suitable lubricant to reduce friction between the sealing surface 304d and oilfield equipment 104 (as shown in Figure 1), including, but not limited to, drilling fluid compatible chip (free from chips) ), grease, oil and the like. The lubrication cavity 700 may have one or more ports 704 for fluid communication with the sealing surface 304D. The one or more ports 704 may have any suitable configuration (and suitable hole diameter) including, but not limited to, spiral ports, and the like. Lubrication cavity 700 can be loaded with lubricant 702 through a grease fitting 706. Lubricant 702 can be released using any suitable method, including, but not limited to, compression of the sealing member 302d, an injection system , and the like. The injection rate of lubricant 702 can be based on any suitable method, including, but not limited to, injection rate influenced by well bore pressure, seal member wear rate 302d and the like. In embodiments, such as those shown in Figures 7-9, when using borehole pressure, such as modality may be more applicable for the lower seal 102 in a double or higher stacked seal system.
    [030] Figure 8 represents the 102g seal in another modality. Seal 102g may have frame 300e, seal member 302e and an outer lubricant reservoir or inflatable bladder 800. The outer lubricant reservoir or inflatable bladder 800 can provide any suitable lubricant 702 for the seal surface 304e through one or more 802 ports on seal member 302e. As shown, the outer lubricant reservoir or inflatable bladder 800 is an annular reservoir around the outer surface of the sealing member 302e, although it may have any suitable configuration. The outer lubricant reservoir or inflatable bladder 800 can deliver lubricant 702 to the sealing surface 304e using any suitable method, including, but not limited to, using well bore pressure to compress the reservoir, using an accumulator, piston, any method described herein and the like.
    [031] Figure 9 represents the 102h seal in another modality. Seal 102h has frame 300f, sealing member 302f and a lubricant reservoir 900. The lubricant reservoir 900, as shown, is located within frame 300f. Lubricant reservoir 900 can provide any lubricant suitable for the sealing surface 304f, including, but not limited to, the lubricants described herein. The lubricant reservoir 900 can fluidly communicate with one or more ports 902 configured for supplying the lubricant to the sealing surface 304f. In one embodiment, a piston 904 can increase the fluid pressure in the lubricant reservoir 900 in order to supply lubricant 702 to the sealing surface 304f. Piston 904 can be controlled to deliver lubricant as needed on RCD 114 (as shown in Figure 1). Although the lubricant reservoir 900 is shown to be activated by means of piston 904, a suitable device can be used to deliver lubricant 702 to the sealing surface 304f, including, but not limited to, one or more accumulators, gravity, well pressure, and the like.
    [032] Figure 10 illustrates seal 102i in another alternative embodiment. Seal 102i has frame 300g, sealing member 302g, and one or more wear buttons 1000. The one or more wear resistant buttons 1000 can be configured to clamp within sealing member 302g close to sealing surface 304g. The one or more wear-resistant buttons 1000 may be cylindrical members molded on the sealing surface 304g of sealing member 302g. In one embodiment, the one or more wear-resistant buttons 1000 can have a diameter of 1.27 centimeters (0.5 inches) and a length of 2.54 centimeters (one inch), however, the wear-resistant buttons 1000 can have any suitable diameter and length. One or more wear-resistant buttons 1000 can be configured to reduce wear on the sealing member 302g during operations. The one or more wear-resistant buttons 1000 can be molded into the sealing member 302g and milled, or cut to the inside diameter of the sealing surface 304g in a similar way as the inserts 600 in Figure 6. Wear-resistant buttons 1000 can be constructed of any suitable material, including, but not limited to, nylon, and any of the materials described in conjunction with one or more inserts 600, and so on. The wear-resistant buttons 1000 can be located in any suitable position on the sealing surface 304g. For example, wear-resistant buttons 1000 can be located along the entire length of the sealing surface 304g, along only the bottom one-third of the sealing surface 304g, along only one half of the sealing surface 304g, and the like.
    [033] Figure 11 illustrates seal 102j in another embodiment. Seal 102j has frame 300h, sealing member 302h, and one or more wear-resistant jaws 1100. One or more wear-resistant jaws 1100 can be configured to penetrate the entire sealing member 302h at a location close to the surface of sealing 304h. As shown, one or more wear-resistant grippers 1100 penetrate the sealing member 302h in a substantially radial or horizontal manner. A nose 1102 of each of the wear-resistant jaws 1100 can be configured to engage oil field equipment 104 (as shown in Figure 1) during oil field operations. The one or more wear-resistant claws 1100 can be wear-resistant and / or slippery in order to reduce the stress on the sealing member 302h. The one or more wear-resistant claws 1100 can be constructed from any suitable material, including, but not limited to, metals, ceramics, a compound, any material described herein for inserts and / or wear buttons, and the like. One or more wear-resistant claws 1100 can be actuated for the sealing member 302h any suitable time after the sealing member 302h is molded.
    [034] A head 1104 of one or more wear-resistant jaws 1100 may have a larger diameter than a rod 1106 of wear-resistant jaws 1100. For example, head 1104 may have a diameter of one inch (2.54 centimeters) ), or any other suitable diameter, including, greater than an inch (2.54 centimeters) or less. The sealing member 302h may have a jaw cavity 1108 close to the head 1104 of the wear jaw. Claw cavity 1108 may allow one or more wear-resistant claws 1100 to travel radially with respect to oil field equipment 104 during oil field operations. Head 1104 can be exposed to well bore pressure during oil field operations. Well bore pressure can provide a driving force on head 1104 that pushes one or more wear jaws radially towards oil field equipment 104. Therefore, well bore pressure can act to force, or press, to one or more wear grips in engagement with oilfield equipment. The head 1104 can be slightly angled with respect to the longitudinal axis of the wear-resistant jaw 1100. The angle can be configured to allow the head 1104 to match the outer angle of the sealing member 102j. The head 1104 may also have one or more notches formed on the outer diameter of the head 1104. The one or more notches may allow fluids in the claw cavity to pass through them when the head moves radially within the claw cavity 1108.
    [035] Figure 12 illustrates seal 102k in another embodiment. Seal 102k has frame 300i, sealing member 302i, one or more wear-resistant jaws 1100 described above, and a tension ring 1200. One or more wear-resistant jaws 1100 can be configured in a similar manner as as described here. The tension ring 1200 can be configured to engage the head 1104 of the wear-resistant jaws 1100. The tension ring 1200 can apply a force to the head 1104 thereby forcing, or pressing, the wear-resistant jaws 1100 radially towards the equipment. oil field 104 (as shown in Figure 1). The tension ring 1200 having an appropriate outside diameter can also seal the claw cavity 1108. The tension ring 1200 can be an elastic material that is slightly stretched, or tensioned, to be engaged with the head 1104. A tension provides strength to head 1104. Tension ring 1200 can be made of any suitable material, including, but not limited to, a rubber, elastomeric material, helical spring and the like.
    [036] Figure 13 represents the seal 1021 in another embodiment. Seal 1021 has frame 300j, seal member 302j, and one or more seal rings 1300. One or more seal rings 1300 can be configured to be inserted into one or more ring cavities 1302 located around the outside diameter sealing member 302 j. Ring cavities 1302 can be of any suitable width and depth. In one example, ring cavities 1302 can be between 1.27 centimeters (0.5 inches) and 2.54 centimeters (one inch) wide.
    [037] The 1300 sealing rings can be constructed of an elastomer having 400 to 450 percent elongations. Sealing rings can be constructed of any suitable material, including, but not limited to, an elastomer, rubber, coil spring and the like. The one or more sealing rings 1300 can be stretched and placed in each of the ring cavities 1302 after the sealing member 302j has been molded. Installed or preloaded, seal rings 1300 can have about twenty to thirty percent elongation that presses seal member 302j radially toward oil field equipment 104 (as shown in Figure 1). Therefore, the sealing rings can force, or feed, the material on the sealing surface 304j to the oil field equipment 104 when the material wears out. This force on the oil field equipment 104 can help the sealing member 302j transfer torque to the oil field equipment even if the sealing member 302j wears out. In addition, seal rings 1300 can prevent divisions in seal member 302j, or keep divisions in a compressed or closed position, during oil field operations.
    [038] Seal 1021 can only be used on double-element RCDs 114 (as shown in Figure 1) in one embodiment. The sealing rings 1300 can aggravate the inversion of the sealing member 302j during suppression under a high differential pressure. However, in the double-element RCD 114 only the lower element is exposed to high well-hole pressures. Therefore, the upper element can benefit more from having the sealing member 302j as the upper element would not be exposed to high differential pressure. In addition, because the sealing rings 1300 feed the sealing member 302j to the oil field equipment, the sealing member 302j can wear out more quickly than a normal sealing member. In the double element RCD 114, however, the increase in the wear rate of seal 1021 can be similar to the wear rate of the lower element.
    [039] Figure 14 shows the 102m seal in another mode. Seal 102m has the frame or assembly 300k, the seal component 302k and a barrier or support structure 1400. The support structure 1400 can be configured to prevent the seal member 302k from reversing during suppression of oil field equipment 104. The support structure 1400 can be located on the inside diameter of the sealing member 302k in order to provide support to resist the forces created by pressure, pipe movement, etc. As shown, support structure 1400 has a top 1402, an upper seal portion 1404, a lower seal portion 1406 and a mounting ring 1408. The top 1402 can be configured to hold support structure 1400 in frame 300k 102m sealant during oil field operations. The mounting ring 1408 can couple with the support structure 1400 and the frame 300k. The top 1402 can be integral with the mounting ring 1408, or the mounting ring 1408 can be held in place, or sandwiched between, frame 300k and the upper sealing portion 1404 of the support structure 1400. As shown, the assembly 1408 has one or more profiles 1410 configured to engage matching profiles in the 300k frame. The one or more profiles 1410 may allow mounting ring 1408 and, thus, the support structure 1400 to rotate in relation to the frame 300k, avoiding relative longitudinal movement.
    [040] The upper sealing portion 1404 can extend on seal 102m parallel to the longitudinal axis of seal 102m. The upper sealing portion 1404 together with the lower sealing portion 1406 can be a tube, or have one or more blades 1412, or bands, as shown. The 1412 blades can be about 1.27 centimeters (0.5 inches) wide in one embodiment, although it should be understood that the blades can be any suitable width, including, but not limited to, extending around the entire the inner circumference of the seal 102m. Blades 1412 can act in a similar way or function as or as a leaf spring. Optionally, the lower sealing portion 1406 may extend along the inner wall of the inner frustroconic surface 312 of seal 102m. The lower sealing portion 1406 can have a minimum inner diameter Dm that is larger than the largest tool joint to be made in the well bore 106 (as shown in Figure 1). The lower sealing portion 1406 can prevent the sealing member 302k from being pulled into the inside diameter of the seal 102m during suppression.
    [041] The modality of Figure 14A is similar to the modality of Figure 14, but it decreases the potential for contact between oilfield equipment 104 and the lower seal portion 1406 by having a shorter lower seal portion 1406 (ie, a lower sealing portion 1406 which can terminate approximately intermediate the length of the inner frustroconic surface 312). In one embodiment the blades 1412a terminate intermediate to the inner frustroconic surface 312. In Figure 14A, the lower sealing portion 1406 extends less along the inner wall of the inner frustroconic surface 312 than the embodiment in Figure 14, thus relatively increasing the inner diameter from the support structure 1400 (in relation to the minimum inner diameter Dm of the embodiment of Figure 14) to an intermediate inner diameter D 1 As the intermediate inside diameter D1 is increased in relation to the minimum inside diameter Dm, oilfield equipment 104 is less likely to scrape or interfere with support structure 1400 which extends the life of oilfield equipment 104.
    [042] Figure 15 illustrates seal 102n in another embodiment. Seal 102n has frame 3001, sealing member 3021, and one or more inner supports 1500. Inner supports 1500 can be a support, or column, for adding stiffness to the sealing member 3021. Increasing the rigidity of the seal 3021 can prevent inversion of seal member 3021 during suppression of oil field equipment 104. The one or more inner supports 1500 can be constructed by molding a support cavity 1502 to the seal member 3021. Support cavity 1502 , as shown extends from a location close to frame 3001 to a location close to the sealing surface 3041 of the sealing member 3021. The support cavity 1502 can be about 1.27 centimeters (0.5 inches) wide to a transition zone 1504 of the sealing member 3021, although it is to be understood that the support cavity 1502 can be of any suitable width along the length of the support cavity 1502. The cavity support material 1502 can be filled with a curing substance 1506 configured for a semi-solid, such as a thermoplastic, meltable silicone, or phenolic resin. The semi-solid can provide resistance and rigidity to the 3021 sealing member against inversion. A cap or fitting 1508 can be placed over the open end of the support cavity 1502 to seal the curing substance 1506 in the support cavity 1502. In another embodiment, a door (not shown) can fluidly couple the frame 3001 to the cavity support 1502 in order to inject curing substance 1506 into support cavity 1502 through frame 3001. Any suitable device can be used to inject curing substance 1506 into support cavity 1502, including, but not limited to a, a grease gun, a caulking gun, and the like.
    [043] Figure 16 illustrates the seal 102o in another embodiment. Seal 102o has frame 300m, sealing member 302m, and one or more tension bars 1600 (by way of example, only six or eight can be incorporated). To one or more tension bars 1600 add resistance to forces caused by pressure, pipe movement, etc. For example, tension bars 1600 can prevent or inhibit the sealing member 302m from axial movement during suppression of the oil field equipment 104 The tension bars 1600 can be molded or attached to the sealing member 302m. As shown, the lower end 1602 of tension bars 1600 can be coupled to each other with a tension ring 1604. Tension ring 1604 can be sized to allow the largest tool joints to pass through it, or can be constructed an elastic (or flexible) material that allows tension ring 1604 to expand and contract during oil field operations. In another embodiment, the tension bars 1600 can be attached or pressed to the outer surface of the frustroconic 310 and the frame 300m with fasteners 1606 (optionally including a plate / ladle to keep down and with the tension ring 1604 replaced by fasteners 1606) .
    [044] The tension bars 1600 can extend from the nose of the sealing member 302m to the frame 300m. As shown, tension bars 1600 are attached to the frame 300m with one or more fasteners 1606. One or more tension bars 1600 can be constructed of any suitable material, including, but not limited to, a metal, a ceramic, any material described here, and the like. The one or more tension bars 1600 can flex during oilfield operations in order to accommodate the elongation of the sealing member 302m. The one or more tension bars 1600 can be tied, or tied with wire, together to prevent tension bars 1600 from falling into well bore 106 (as shown in Figure 1).
    [045] Figure 16A illustrates seal 102v in another mode, in which the characteristics of the modes shown in Figure 14 and Figure 16 are combined. Seal 102v has frame 300r, sealing member 302r, sealing surfaces 304p, a support structure 1400, and one or more tension bars 1600 (for example, only six or eight can be incorporated). The one or more tension bars 1600 can prevent the sealing member 302r from reversing during suppression of oil field equipment 104. The tension bars 1600 can be molded or attached to the sealing member 302r. As shown, the lower end 1602 of tension bars 1600 can be coupled to each other with a tension ring 1604. Tension ring 1604 can be sized to allow the largest tool joints to pass through it, or can be constructed an elastic (or flexible) material that allows tension ring 1604 to expand and contract during oil field operations. In another embodiment, the tension bars 1600 can be attached or pressed to the outer surface of the frustroconic 310 and the frame 300m with fasteners 1606 (optionally including a retaining plate / shell at the bottom and with the tension ring 1604 replaced by fasteners 1606) .
    [046] The tension bars 1600 can extend from the nose of the sealing member 302r to the frame 300r. As shown, tension bars 1600 are attached to frame 300r with one or more fasteners 1606. One or more tension bars 1600 can be constructed of any suitable material, including, but not limited to, a metal, a ceramic, any material described here, and the like. The one or more tension bars 1600 can flex during oil field operations in order to accommodate the elongation of the sealing member 302r. The one or more tension bars 1600 can be tied, or tied with wire, together to prevent tension bars 1600 from falling into well bore 106 (as shown in Figure 1).
    [047] The support structure 1400 in Figure 16A can be configured to prevent the sealing member 302r from reversing during suppression of the oil field equipment 104. The support structure 1400 can be located on the inside diameter of the sealing member 302r in order to avoid inversion. As shown, the support structure 1400 has a top 1402, an upper seal portion 1404, a lower seal portion 1406 and a mounting ring 1408. The top 1402 can be configured to hold support structure 1400 in frame 300r of the 102v seal during oil field operations. The mounting ring 1408 can couple with the support structure 1400 and the frame 300r. The top 1402 can be integral with the mounting ring 1408, or the mounting ring 1408 can be held in place, or sandwiched between, the frame 300r and the upper sealing portion 1404 of the support structure 1400. As shown, the ring assembly 1408 has one or more profiles 1410 configured to engage matching profiles in frame 300r. The one or more profiles 1410 may allow the mounting ring 1408 and thus the support structure 1400 to rotate with respect to frame 300r, while preventing relative longitudinal movement.
    [048] The upper sealing portion 1404 can extend into the seal 102v parallel to the longitudinal axis of the seal 102v. The upper sealing portion 1404 together with the lower sealing portion 1406 can be a tube, or have one or more blades 1412, or bands, as shown. Blades 1412 can be about 1.27 centimeters (0.5 inches) wide in one embodiment, although it should be understood that blades 1412 can be any suitable width, including, but not limited to, extending around the entire the inner circumference of the 102v seal. Blades 1412 can similarly act as a leaf spring. Optionally, the lower sealing portion 1406 can extend along the inner wall of the frustroconic inner surface 312 of seal 102v. The lower sealing portion 1406 can have a minimum inside diameter Dm (or as shown in the embodiment of Figure 14A an intermediate diameter) which is larger than the largest tool joint to be made in the well hole 106 (as shown in Figure 1 ). The lower sealing portion 1406 can prevent the sealing member 302r from being pulled into the inside diameter of the seal 102v during suppression.
    [049] Figure 17A shows a side view of seal 102p in another embodiment. Figure 17B shows a cross-sectional view of seal 102p in this embodiment. Seal 102p may have frame 300n similar to any of frames 300 described herein. The sealing member 302n of the seal 102p can have a plurality of sealing segments 1700. The sealing segments 1700 can swell out along their outer surface 1702. The outer bulging surface 1702 can give the outer surface an appearance similar to a pumpkin. As shown in Figure 17B, the protrusions can begin at a location on the outer surface of the sealing member 302n close to the sealing surface 304n. In one example, the protrusions begin about halfway to the sealing surface 304n. The protrusions can be formed by molding, or by compression of the mold before curing is complete, or a combination of these. By compressing the sealing member 302n to form the protrusions the sealing member 302n may have a prestress to push down. The protrusions may become progressively more pronounced up to the outer surface 1702 towards the frame 300n. The increased cross-sectional area of the sealing member 302n provided by the protrusions can prevent inversion of the sealing member 302n and decreased vector forces (caused by well bore pressure and "decreased" as discussed here in context is relative to vector forces of well bore experienced by, for example, frustroconic surface 310 of the modality of Figure 3) on the sealing surface 304n thus reducing wear of the sealing member. Lumps can flatten when suppressing instead of reversing due to the increased cross-sectional area. The wall thickness or width W of the protrusions can be adjusted to decrease the likelihood of inversion.
    [050] Sealing member 302n may be under tension when engaged with oil field equipment 104 (as shown in Figure 1). For example, the sealing member 302 may have an extension snap around the oil field equipment 104. The protrusions in the sealing segments 1700 may allow the sealing member 302n to expand when the tool joints pass through the sealing member. seal 302n.
    [051] The sealing member 302n, or any other sealing members 302 described herein, may have one or more abrasion resistant bars molded into the sealing member 302n. The abrasion resistant bars can be made of any suitable material, including, but not limited to, nylon, and the like. Abrasion resistant bars can aid in the formation of protrusions in each of the 1700 sealing segments.
    [052] Figure 18 shows a cross-sectional view of seal 102q in another embodiment. Seal 102q has frame 300o, sealing member 302o, and one or more seal inserts 1800. As shown, seal inserts 1800 can be a threaded seal insert 1800a, or an annular seal insert 1800B. The sealing inserts 1800 can be located in a sealing profile 1802 molded on the inner wall of the sealing surface 304o. The threaded seal insert 1800a can be threaded on the seal profile 1802a of the seal surface 304o in order to secure the seal insert 1800a on the seal member 302o. The 1800B ring seal insert can be forced into the 1802b seal profile. The ring seal insert 1800b and / or seal profile 1802b may have a J-latch, or latch in another way to secure the seal insert 1800b to the seal profile 1802b. Although the sealing inserts 1800 are described as threaded or annular, it should be noted that the sealing inserts 1800 can be of any suitable form provided that the sealing inserts 1800 seal the inner circumference of the sealing surface 304o.
    [053] Sealing inserts 1800 can be configured to engage oil field equipment 104 (as shown in Figure 1) during oil field operations. The sealing inserts can be 1.27 centimeters (0.5 inches) to 2.54 centimeters (one inch) thick in one embodiment, although any suitable thickness can be used. Thus, the sealing inserts 1800 can extend radially inward beyond the inner diameter of the sealing surface 304o. In this mode, only the 1800 sealing inserts wear out during oil field operations. Therefore, only the sealing inserts 1800 need to be replaced during the life of the 102q seal and the sealing member 302o is reusable. The sealing inserts 1800 can push the outer circumference of the sealing member 302o close to the nose end when compared to the normal sealing member.
    [054] The material of the sealing inserts 1800 can be configured to meet the needs of the particular oil field operations to be carried out. For example, 1800 sealing inserts may have material properties optimized for sealing oilfield equipment 104. Since only 1800 sealing inserts engage oilfield equipment 104, the material of 1800 sealing inserts can be a more costly and efficient, while using any suitable material in the 302o sealing member and other equipment. Because the wall thickness of the shell in the nose area of the sealing member 302o holding the sealing insert 1800 is less, additives that would otherwise make the sealing member 302o very difficult to pierce may be permitted throughout the sealing member 302o . Additives can include, but are not limited to, HIPERSTRIP and the like, and can be constructed from any of the materials found in U.S. Patent No. 5,901,964 which is incorporated herein by reference in its entirety.
    [055] In another embodiment, on a double-element RCD 114, the material of sealing inserts 1800 may vary between each element according to the operations being performed. For example, a wear-resistant material can be used for 1800 sealing inserts in the top element and a lubricating material can be used in 1800 sealing inserts in the bottom element to reduce heat generation from having the differential pressure weight. .
    [056] Sealing inserts 1800 may vary in size depending on the size of oil field equipment 104. Therefore, sealing inserts 1800 can be replaced when a larger or smaller drill pipe is being run through RCD 114. In one embodiment, the sealing inserts 1800 can be replaced without having to remove the entire sealing member 302o from the inner stroke of the bearing assembly. In addition, the same size sealing member 302o can be used for a number of differently sized pieces of oilfield equipment 104 (for example, pipe sizes). Therefore, the same sealing member 302o can be used for a number of different pipe sizes for a specific RCD model.
    [057] Figure 19A shows a cross-sectional view of seal 102r in another embodiment. Seal 102r may have frame 300p, and seal members 302p similar to any of frames 300 and seal members 302 described herein. Seal 102r can also have a plurality of sealing surfaces 1900 contained in a cartridge 1902. Cartridge 1902 can be a tube for containing sealing surfaces 1900. Cartridge 1902 can be made of any suitable material, including, but not limited to a, a metal, a reinforced thermoplastic material, a ceramic, a compound, and the like. The cartridge 1902 may be of any suitable length to contain a plurality of sealing surfaces 1900, including, but not limited to, 1.22 m (four feet) in length, or less than 1.22 m (four feet) in length , or greater than 1.22 meters (four feet) in length.
    [058] The plurality of sealing surfaces 1900 can be attached to cartridge 1902. The uppermost sealing surface 1900 can be a molded sealing member 1903. The molded sealing member 1903 can be located above the lower sealing surfaces 1900. The lower sealing surfaces 1900 may comprise one or more packers 1904. The molded sealing member 1903 may be similar to any of the sealing members 302 described herein. However, the molded sealing member 1903 may have a molded nose 1906 configured to match the shape of the packers 1904 thus creating an annular space 1908 between the molded sealing element 1903 and the uppermost packer 1904. The molded sealing member 1903 it may be suitable for transmitting torque to oil field equipment 104 (as shown in Figure 1). The differential pressure between the one or more packers 1904 and the molded sealing member 1903 can be controlled to reduce wear and tear on the sealing surfaces 1900. The inner ends of the 1904 packers can be angled for optimal intersecting characteristics with the oil field equipment 104.
    [059] The differential pressure between the 1904 packers and / or the molded sealing member 1903 can be controlled using any suitable method. For example, after oil field equipment 104 is drilled in seal 102r, ring space 1908 can be packed with grease with a grease gun. The pressure in the well bore 106, and / or the differential pressure sharing in the drilling column can control the differential pressure between the 1908 ring spaces. In addition, the rotation of the 102r seal and / or the differential pressure sharing with the column hole can control the pressure in the 1908 ring spaces. A fitting 1920 can be located at the end of each of the 1908 ring spaces to fill the 1908 ring spaces with grease and / or other fluid.
    [060] Figure 19B shows a detail of the lower frame 300p and the lower sealing member 302p of the modality of Figure 19B to control the differential pressure between ring spaces 1908. Wear and tear can be reduced by controlling the differential pressure. A 1912 valve can be installed near the bottom frame 302p. The 1912 valve can be any suitable valve, including, but not limited to, a check valve, a one-way valve, a relief valve and the like. A 1916 spring can be designed to allow the 1912 valve to open at some preset pressure (for example, three hundred psi). An optional 1914 filter can be used to prevent debris from ring returns from entering seal 102r. When the 1912 valve opens, returns can introduce above the lower frame 300p through a 1918 relief port. In another embodiment, the 1912 valve can be replaced by holes of varying sizes, or ports to control the pressure between each of the 1904 packers. The 1912 valve (s), and / or the orifices, can be sized to approximate differential pressure sharing in the 1908 ring spaces. In an additional embodiment, there may be one or more 1912 valves, and / or orifices, formed by the packers 1904 in order to communicate fluidly between the annular spaces 1908. In yet another embodiment, one or more 1912 valves, or orifices, can be located through the wall of the 1902 cartridge in order to expose the annular space 1908 to well-hole pressure 106.
    [061] Figure 20A shows a cross-sectional view of a portion of RCD 114a having the seal (s) 102s according to another embodiment. As shown, seal (s) 102s have two 300q frames (shown schematically) and three 302q seal members (an upper seal member 302q connected to the top end of the inner stroke 2002 is the same size and shape as the seal members 302q below). Two of the 302q sealing members (the lower two as shown) can be stacked on a 2000 sealing adapter. The 2000 sealing adapter can be configured to couple RCD 114 and 300q frames. As shown, the sealing adapter 2000 engages below an inner stroke 2002 of RCD 114a. The upper-lower seal member 302q can be located inside the seal adapter 2000, while the lower seal member 302q can hang below the seal adapter 2000.
    [062] Sealing adapter 2000 can be configured to rotate with sealing member 302q in relation to RCD 114a in one mode. In an alternative embodiment, the sealing adapter 2000 can be rotatably fixed, and the sealing members 302q can be configured to rotate in a support profile 2004 of the sealing adapter 2000. A sealing adapter cavity 2006 between the sealing members top-bottom and bottom 302q can be packed with grease, or other suitable fluid. Grease can be temperature sensitive in relation to flow with RCD 114a. The grease can be injected into the sealing adapter cavity 2006 through one or more holes 2008 in the sealing adapter 2000. In one embodiment, the centrifugal force can be used to force the grease towards the oil field tool 104 during drilling operations. oil field.
    [063] The sealing members 302 can be the same or different sealing members 302q depending on the oil field operations to be performed. In one embodiment, the sealing members 302q are standard sealing members. In addition, the sealing members 302q can be any combination of the sealing members 300 described herein. In addition, the sealing adapter 2000 to which both sealing members are attached can be built at least partially from horizontally corrugated material (not shown) to accommodate misalignment or bending of oil field equipment 104 and to relieve some load side of the bearing. The sealing adapter (s) (2000 housings or cartridges) and / or frames 300q for the sealing members 302q can, for example, be made of reinforced rubber.
    [064] Figure 20B shows an embodiment of a portion of seal 102s. In this embodiment, the one or more 300q frames and / or 302q sealing members can have a 2010 relief valve (such as, for example, a check ball) in fluid communication with a 2011 relief port. The 2010 relief valves with springs 2014, and filter medium 2012, they can be adjustable double-acting relief valves that allow the 2006 sealing adapter cavity to communicate fluidly with well-hole pressure. Fluid communication between the well hole pressure and the 2006 sealing cavity adapter can achieve a differential pressure sharing rate. Please see patent publication No. US 2011/0024195, entitled "Drilling with a High Pressure RCD", the disclosure of which is hereby incorporated by reference. In another embodiment, the sealing adapter may have an opening door (not shown) configured to communicate fluidly with the borehole pressure. In this embodiment, the upper-lower sealing member 302q can be exposed to a higher differential pressure, while the lower sealing member 302q can only be exposed to mud suppression with an extension clamp.
    [065] Figure 21 shows a cross-sectional view of seal 102t according to another embodiment. Seal 102t has a mounting frame 300t, a seal housing 2100, a pressed seal member 2102, and a pressure system 2104. The seal housing 2100 is configured to mate for RCD 114 and houses the pressed seal member 2102. The pressed seal member 2102 can be located inside the seal housing 2100 and pressed radially towards oil field equipment 104. As shown, the pressed seal member 2102 is coupled to the housing at each end of the seal member pressed 2102. The pressed seal member 2102 can have strategically connected areas to reduce the effects of pressure from well bore 106 (as shown in Figure 1). In addition, the pressed sealing member 2102 may have steel reinforcement (not shown) in weak areas. Pressure system 2104 as shown is a piston 2106 (which can be assisted by well-hole pressure) pressed by a helical spring 2108 although it can be any suitable system, including, but not limited to, a seal ring, a spring blade, and the like. The pressure system presses the pressed sealing member 2102 to engage with oil field equipment 104 during oil field operations. The pressed sealing member 2102 can be constructed of and includes any materials (for example, elastomeric) and / or devices described in conjunction with the sealing members 302 described herein.
    [066] Figure 22 illustrates seal 102u in another embodiment. Seal 102u is similar to seal 102t shown in Figure 21, and has a 300U mounting frame; however, pressure system 2104 is a seal ring 2200. Seal ring 2200 can wrap around the pressed seal member 2102. As shown, seal ring 2200 is an elastic tube that can, for example, be surrounded by chamber 2110 preloaded by hydraulics or pneumatics, for example, an inert gas. Chamber 2110 can be preloaded via Zirk 2112 fitting with a pressure that presses on the sealing member 2102 to engage with oilfield equipment 104. As the temperature rises at seal 102u, the gas in chamber 2110 expands thus increasing the pressure in the pressed sealing member 2102.
    [067] Figure 23 shows an RCD 114 having a 2300 motor to rotate an inner drum 2302 from RCD 114. The 2300 motor is configured to positively / directly rotate the inner drum, or stroke, 2302 at a rotation speed to match the top drive, or other rotation device, that rotates the oilfield equipment. The 2300 motor can be any suitable motor, or motive member, including, but not limited to, an electric motor, a hydraulic motor, an air motor, etc. The 2300 engine can be a variable speed engine to match the rotational speed of the oilfield equipment. One or more gears 2304 can be configured to transmit energy from the motor 2300 into the drum 2302. In addition, one or more gears 2304 can be configured to control the rotation speed of the inner drum 2302. To one or more gears 2304 can be any suitable gears including, but not limited to, worm gear, toothed gears, a gear stroke, and the like. The power supply for the 2300 engine can be powered and speed controlled from an RCD 114 hydraulic power unit. The 2300 engine may be able to rotate the inner drum 2302 to any suitable RPM, including, but not limited to , two hundred RPM at about 120 feet / lbs. (80.64 m / kg) of torque capacity.
    [068] The inner drum 2302 can couple with the seal 102s as shown in Figures 20A and 20B. In addition, the inner drum 2302 can couple to any of the seals 102 described herein in order to rotate the seal 102 with the oil field equipment. The motor 2300 can be configured to assist the ability of seals 102 and / or sealing members 302 to rotate the inner drum, or stroke. In addition, motor 2300 can positively drive inner drum 2302 and thus seals 102 at a substantially similar rate as oil field equipment. This can substantially reduce the wear of the sealing members 302 during the service life of the seals 102.
    [069] Figure 24 represents RCD 114 having one or more power transmission vanes 2400 configured to rotate inner drum 2302. In one embodiment, seal 102s of Figures 20A and 20B can couple with inner drum 2302 and rotate with the same, although any of the seals described here can be used in conjunction with the 2400 power transmission vanes. One or more 2400 power transmission vanes can be configured to mate with the outer diameter of the inner drum 2302 and be attached to the inner bearing 2402. Thus, the one or more power transmission vanes 2400 rotate the inner bearing 2402 and thus the one or more seals 102 are rotated. The one or more power transmission vanes 2400 may be similar to a turbine, or fan, which is powered by a flow of fluid against the 2400 vanes.
    [070] As shown, a 2404 hydraulic power unit (HPU) can supply hydraulic fluid to one or more 2400 power transmission vanes to rotate the 2400 power transmission vanes and thus the seals 102. The rate flow and pressure of the HPU 2404 can be directly influenced by the rotation speed of the top drive. This configuration can assist the ability of the sealing members 302 to rotate inside the drum as opposed to trying to synchronize / match the speed of the inner drum with the speed of the top drive. In one embodiment, one or more 2400 power transmission vanes connect to the adapter, or other course, located between an upper and lower seal 102 of a double-element RCD.
    [071] The components of the seals 102 described herein can be exchanged for all sealing members 302 and frames 300, depending on the type of oil field operations to be performed.
    [072] Although the modalities are described with reference to various implementations and explorations, it should be understood that these modalities are illustrative and that the scope of the object of the invention is not limited to them. Many variations, modifications, additions and improvements are possible. For example, the techniques used here can be applied to any well BOPs below, ram shears, packers, and the like.
    [073] Plural instances can be provided for components, operations or structures described here as a single instance. In general, structures and features presented as separate components in the exemplary configurations can be implemented as a combined structure or component. Likewise, structures and features presented as a single component can be implemented as separate components. These and other variations, modifications, additions and improvements may fall within the scope of the object of the invention.
    权利要求:
    Claims (15)
    [0001]
    1. Ring seal to seal an item of oilfield equipment, the ring seal characterized by the fact that it has an inside diameter to receive the item of oilfield equipment, comprising: a frame (300); a sealing member (302a) adjoining the frame; where the annular seal is configured for durability; wherein the sealing member comprises a substantially frustroconic outer surface (310), a substantially frustroconic inner surface (312), and a sealing surface (304); wherein the sealing member (302a) includes a sealing area around the sealing surface (304); and wherein the sealing area includes at least one additive (306) arranged radially on the sealing surface (304).
    [0002]
    2. Apparatus according to claim 1, characterized by the fact that said additive is made of a volume of wear-resistant material selected from the group of wear-resistant materials consisting of ceramics, nylon, beryllium chips, molybdenum , aramid fibers and hydraulic fracture propellants.
    [0003]
    3. Apparatus, according to claim 1, characterized by the fact that said additive has a shape selected from the group of shapes that consist of spherical, irregular, globular shape, fiber type, crystalline shape and BB with a rough surface.
    [0004]
    4. Apparatus according to claim 1, characterized by the fact that the at least one additive is integral with the sealing member.
    [0005]
    5. Apparatus according to claim 4, characterized by the fact that the sealing member further comprises a nose close to the substantially frustroconic outer surface and the sealing surface; and in which said additive is integral to the nose only.
    [0006]
    6. Apparatus according to claim 4, characterized by the fact that said additive comprises a pelleted aramid pulp material.
    [0007]
    7. Apparatus according to claim 4, characterized by the fact that said additive is phenolic attached to the sealing member.
    [0008]
    8. Apparatus according to claim 4, characterized in that said additive includes a means for adding elasticity to the sealing member.
    [0009]
    9. Apparatus according to claim 1, characterized by the fact that it further comprises: a support structure (1400) mounted on the inside diameter of the sealing member.
    [0010]
    Apparatus according to claim 9, characterized in that said support structure comprises: a top, an upper sealing portion and a lower sealing portion; and wherein the top is configured to retain said support structure in the frame.
    [0011]
    Apparatus according to claim 10, characterized in that the sealing member comprises a substantially frustroconic outer surface, a substantially frustroconic inner surface, and a sealing surface; wherein the upper sealing portion of said support structure extends to the sealing member parallel to a longitudinal axis of the sealing member; and wherein the lower sealing portion of said support structure extends along the substantially frustroconic inner surface.
    [0012]
    Apparatus according to claim 11, characterized in that the lower sealing portion ends intermediate at a length of the substantially frustroconic inner surface and defining an intermediate inner diameter greater than the inner diameter of the annular seal.
    [0013]
    13. Apparatus according to claim 1, characterized by the fact that the sealing member is treated with a volume of a chemical treatment selected from the group of chemical treatments consisting of SULFRON, TWARON aramid, and PROAID LCF.
    [0014]
    Apparatus according to claim 1, characterized in that the sealing member comprises a substantially frustroconic outer surface, a substantially frustroconic inner surface, and a sealing surface; wherein the sealing member has an annular cavity around the outer periphery of the substantially frustroconic outer surface of the sealing member; and further comprising at least one sealing ring (1300) inserted in the annular cavity in which the sealing ring is made of an elastomeric material.
    [0015]
    15. Apparatus according to claim 1, characterized by the fact that it also comprises a lubricant additive applied to the sealing surface of the sealing member.
    类似技术:
    公开号 | 公开日 | 专利标题
    BR112014016321B1|2020-11-17|annular seal on a rotary control device
    EP1071862B1|2004-11-03|Rotating subsea diverter
    BR112013009489B1|2020-06-23|SYSTEMS AND METHOD AND APPLIANCES FOR USE WITH AND OPERATION OF A PETROLEUM EXPLORATION DEVICE
    EP2875207A1|2015-05-27|Method and apparatus for string access or passage through the deformed and dissimilar contiguous walls of a wellbore
    BRPI0509344B1|2016-03-01|system and method for assembling well overhaul equipment
    AU2012300923B2|2015-09-03|Disconnecting tool
    BRPI0710352B1|2018-02-06|METHOD FOR REMOVING A WELL HOLE FLUID AND RISER, ROTATING SHAFT, METHOD FOR USING A RECIPROCANT MOVEMENT SHAFT, METHOD FOR REMOVING OIL WELL FLUID AND SEA DRILLING DRILL OIL
    BRPI0806867A2|2012-05-02|oilfield equipment
    EP3039231B1|2018-10-10|Rotating control device with rotary latch
    AU2014205066A1|2015-07-02|Surge immune liner setting tool
    BRPI1104879A2|2013-02-26|System configured to move a socket block into an overflow preventer, System configured to cut an object into an overflow preventer, and Method to cut an object into an overflow preventer.
    US8167050B2|2012-05-01|Method and apparatus for making up and breaking out threaded tubular connections
    CA2812692C|2018-03-13|Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string
    US20150259997A1|2015-09-17|Torque Anchor to Prevent Rotation of Well Production Tubing, System for Pumping and Rotation Prevention, and Pumping Installation Equipped with Such a Torque Anchor
    WO2011015911A2|2011-02-10|Stuffing box assembly
    US10590730B2|2020-03-17|Packer box and method for installation or withdrawal of a packer element in, respectively from a packer box for use in petroleum drilling
    MX2014012000A|2015-05-08|Rotating and reciprocating swivel apparatus and method.
    EP3516157B1|2021-12-08|Combined casing and drill-pipe fill-up, flow-back and circulation tool
    BR102014028614B1|2021-11-23|BALL RELEASE SYSTEM, COATING INSTALLATION ASSEMBLY AND METHOD FOR SUSPENDING AN INTERNAL TUBULAR COLUMN FROM AN EXTERNAL TUBULAR COLUMN
    BR102014028614A2|2015-09-08|ball release system, liner installation assembly and method for suspending an inner tubular column from an outer tubular column
    BR102014028651B1|2021-11-03|OPERATING TOOL FOR INSTALLING A PIPE COLUMN IN A WELL HOLE, LINING INSTALLATION ASSEMBLY AND METHOD FOR SUSPENDING AN INNER PIPE COLUMN
    BR102014028651A2|2015-09-08|operating tool for installing a pipe column in a wellbore, casing installation set and method for suspending an internal pipe column
    OA17621A|2017-04-28|Rotating control device with rotary latch.
    同族专利:
    公开号 | 公开日
    WO2013102131A3|2014-03-20|
    US10053943B2|2018-08-21|
    EP3231986B1|2020-06-17|
    AU2012362225B2|2017-08-24|
    DK3231986T3|2020-09-14|
    AU2012362225A1|2014-07-17|
    CA2861895A1|2013-07-04|
    NO2874727T3|2018-05-05|
    DK2812526T3|2017-11-13|
    BR112014016321A2|2017-06-13|
    US20160273297A1|2016-09-22|
    EP3231986A1|2017-10-18|
    EP2812526B1|2017-08-09|
    EP2812526A2|2014-12-17|
    CA2861895C|2020-02-25|
    WO2013102131A2|2013-07-04|
    BR112014016321A8|2017-07-04|
    US20140027129A1|2014-01-30|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    US1901031A|1932-07-25|1933-03-14|Granville A Humason|Pumping apparatus|
    US2458270A|1945-08-25|1949-01-04|Granville A Humason|Gas controller for well pumps|
    US2682068A|1950-11-03|1954-06-29|John J Harrigan|Device for externally cleaning oil well casings and pipes|
    US3023012A|1959-06-09|1962-02-27|Shaffer Tool Works|Submarine drilling head and blowout preventer|
    US3583480A|1970-06-10|1971-06-08|Regan Forge & Eng Co|Method of providing a removable packing insert in a subsea stationary blowout preventer apparatus|
    US4428592A|1982-06-07|1984-01-31|Shaffer Charles D|Mesh reinforced elastomeric element for oil well components|
    US4647050A|1985-07-22|1987-03-03|Anadarko Production Company|Stuffing box for a sucker rod pump assembly|
    US4981174A|1990-02-14|1991-01-01|White Orvel O|Leakproof stuffing box with external lubrication for polish rod|
    US5062479A|1990-07-31|1991-11-05|Masx Energy Services Group, Inc.|Stripper rubbers for drilling heads|
    US5224557A|1991-07-22|1993-07-06|Folsom Metal Products, Inc.|Rotary blowout preventer adaptable for use with both kelly and overhead drive mechanisms|
    US5343944A|1992-09-10|1994-09-06|Grey Bassinger|Self aligning stuffing box for pumpjack units|
    US5636688A|1992-09-10|1997-06-10|Bassinger; Grey|Self aligning stuffing box for pumpjack units|
    US5538080A|1992-09-10|1996-07-23|Bassinger; Grey|Self aligning stuffing box for pumpjack units|
    US5647444A|1992-09-18|1997-07-15|Williams; John R.|Rotating blowout preventor|
    US5662181A|1992-09-30|1997-09-02|Williams; John R.|Rotating blowout preventer|
    US5348107A|1993-02-26|1994-09-20|Smith International, Inc.|Pressure balanced inner chamber of a drilling head|
    US5474097A|1993-11-10|1995-12-12|Atlantic Richfield Company|Scale removal and disposal system and method|
    US5549156A|1995-06-06|1996-08-27|Borden; B. Michael|Shock absorber & Wiper|
    WO1997036087A1|1996-03-25|1997-10-02|Fiber Spar And Tube Corporation|Infuser for composite spoolable pipe|
    US5803169A|1996-12-24|1998-09-08|Auto Pax Products, L.L.C.|Rotary stuffing box and seal assembly|
    US5901964A|1997-02-06|1999-05-11|John R. Williams|Seal for a longitudinally movable drillstring component|
    US6230824B1|1998-03-27|2001-05-15|Hydril Company|Rotating subsea diverter|
    US6325159B1|1998-03-27|2001-12-04|Hydril Company|Offshore drilling system|
    US6227547B1|1998-06-05|2001-05-08|Kalsi Engineering, Inc.|High pressure rotary shaft sealing mechanism|
    US7159669B2|1999-03-02|2007-01-09|Weatherford/Lamb, Inc.|Internal riser rotating control head|
    US6457529B2|2000-02-17|2002-10-01|Abb Vetco Gray Inc.|Apparatus and method for returning drilling fluid from a subsea wellbore|
    US6520253B2|2000-05-10|2003-02-18|Abb Vetco Gray Inc.|Rotating drilling head system with static seals|
    US6910531B2|2001-11-21|2005-06-28|Vetco Gray Inc.|Rotating drilling stripper|
    US6966386B2|2002-10-09|2005-11-22|Halliburton Energy Services, Inc.|Downhole sealing tools and method of use|
    US8826988B2|2004-11-23|2014-09-09|Weatherford/Lamb, Inc.|Latch position indicator system and method|
    US7040394B2|2002-10-31|2006-05-09|Weatherford/Lamb, Inc.|Active/passive seal rotating control head|
    US7836946B2|2002-10-31|2010-11-23|Weatherford/Lamb, Inc.|Rotating control head radial seal protection and leak detection systems|
    US7377334B2|2003-12-17|2008-05-27|Smith International, Inc.|Rotating drilling head drive|
    US7174956B2|2004-02-11|2007-02-13|Williams John R|Stripper rubber adapter|
    US7240727B2|2004-02-20|2007-07-10|Williams John R|Armored stripper rubber|
    US7237618B2|2004-02-20|2007-07-03|Williams John R|Stripper rubber insert assembly|
    FR2882061B1|2005-02-15|2008-04-18|Arkema Sa|ELASTIC MATERIALS|
    AU2006231725A1|2005-04-05|2006-10-12|University College Cork - National University Of Ireland, Cork|Mesoporous particles|
    NO324167B1|2005-07-13|2007-09-03|Well Intervention Solutions As|System and method for dynamic sealing around a drill string.|
    CA2575477C|2007-01-12|2010-11-02|Kenneth A. Travis|Method of forming a sealing element for a blow out preventer|
    NO326492B1|2007-04-27|2008-12-15|Siem Wis As|Sealing arrangement for dynamic sealing around a drill string|
    US20080299391A1|2007-05-31|2008-12-04|White Scott R|Capsules, methods for making capsules, and self-healing composites including the same|
    NO327281B1|2007-07-27|2009-06-02|Siem Wis As|Sealing arrangement, and associated method|
    US7717169B2|2007-08-27|2010-05-18|Theresa J. Williams, legal representative|Bearing assembly system with integral lubricant distribution and well drilling equipment comprising same|
    US7717168B2|2008-04-15|2010-05-18|Theresa J. Williams, legal representative|Reinforced stripper rubber body and method of making same|
    GB0806921D0|2008-04-16|2008-05-21|Airbus Uk Ltd|Composite laminate with self-healing layer|
    US8703285B2|2008-08-19|2014-04-22|The Board Of Trustees Of The University Of Illinois|Interfacial functionalization for self-healing composites|
    US8322432B2|2009-01-15|2012-12-04|Weatherford/Lamb, Inc.|Subsea internal riser rotating control device system and method|
    US8347983B2|2009-07-31|2013-01-08|Weatherford/Lamb, Inc.|Drilling with a high pressure rotating control device|
    NO333082B1|2010-06-16|2013-02-25|Siem Wis As|Grinding string grinding arrangement|
    US9175542B2|2010-06-28|2015-11-03|Weatherford/Lamb, Inc.|Lubricating seal for use with a tubular|
    GB2489265B|2011-03-23|2017-09-20|Managed Pressure Operations|Blow out preventer|
    US20130106712A1|2011-11-01|2013-05-02|Qualcomm Mems Technologies, Inc.|Method of reducing glare from inner layers of a display and touch sensor stack|
    EP3231986B1|2011-12-29|2020-06-17|Weatherford Technology Holdings, LLC|Annular sealing in a rotating control device|
    US9016659B2|2012-06-26|2015-04-28|Hydril Usa Manufacturing Llc|Fiber reinforced elastomer anisotropic annular blowout preventer|EP3231986B1|2011-12-29|2020-06-17|Weatherford Technology Holdings, LLC|Annular sealing in a rotating control device|
    EP3049612A4|2013-09-24|2017-10-18|Halliburton Energy Services, Inc.|Reinforced drill pipe seal with floating backup layer|
    CA2839151C|2014-01-14|2017-12-12|Strata Energy Services Inc.|Modular sealing elements for a bearing assembly|
    AU2015253019B2|2014-04-30|2017-09-07|Weatherford Technology Holdings, Llc|Sealing element mounting|
    MX357894B|2014-05-13|2018-07-27|Weatherford Tech Holdings Llc|Marine diverter system with real time kick or loss detection.|
    US9567817B2|2014-05-29|2017-02-14|Weatherford Technology Holdings, Llc|Rotating control device radial seal protection|
    WO2016028340A1|2014-08-21|2016-02-25|Halliburton Energy Services Inc.|Rotating control device|
    US9844167B2|2015-06-26|2017-12-12|Microsoft Technology Licensing, Llc|Underwater container cooling via external heat exchanger|
    US9801313B2|2015-06-26|2017-10-24|Microsoft Technology Licensing, Llc|Underwater container cooling via integrated heat exchanger|
    US10316413B2|2015-08-18|2019-06-11|Baker Hughes, A Ge Company, Llc|Self-healing coatings for oil and gas applications|
    AU2016346792A1|2015-10-27|2018-02-15|Weatherford Technology Holdings, Llc|Radial seal pressure reduction using internal pump|
    US10731762B2|2015-11-16|2020-08-04|Baker Hughes, A Ge Company, Llc|Temperature activated elastomeric sealing device|
    US10087698B2|2015-12-03|2018-10-02|General Electric Company|Variable ram packer for blowout preventer|
    US10214986B2|2015-12-10|2019-02-26|General Electric Company|Variable ram for a blowout preventer and an associated method thereof|
    US20170204695A1|2016-01-20|2017-07-20|General Electric Company|Self healing blowout preventer seals and packers|
    US10190378B2|2016-07-28|2019-01-29|Weatherford Technology Holdings, Llc|Drilling head with non-rotating annular seal assembly|
    US10494877B2|2017-08-16|2019-12-03|Weatherford Technology Holdings, Llc|Subsea rotating control device apparatus having debris barrier|
    US20190162041A1|2017-11-28|2019-05-30|Weatherford Technology Holdings, Llc|Pressure control device with composite annular seal assembly|
    US11118421B2|2020-01-14|2021-09-14|Saudi Arabian Oil Company|Borehole sealing device|
    US20210254427A1|2020-02-19|2021-08-19|Noble Rig Holdings Limited|Seal elements for annular control devices|
    US20210324700A1|2020-04-21|2021-10-21|Cameron International Corporation|Rotating control device systems and methods|
    US11187056B1|2020-05-11|2021-11-30|Schlumberger Technology Corporation|Rotating control device system|
    US11174698B1|2020-12-18|2021-11-16|Halliburton Energy Services, Inc.|Rotating control device element reinforcement petals|
    法律状态:
    2018-04-10| B25A| Requested transfer of rights approved|Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC (US) |
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2020-01-21| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-07-21| B09A| Decision: intention to grant|
    2020-11-17| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 28/12/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161581427P| true| 2011-12-29|2011-12-29|
    US61/581,427|2011-12-29|
    PCT/US2012/072156|WO2013102131A2|2011-12-29|2012-12-28|Annular sealing in a rotating control device|
    [返回顶部]