WO1994020728A1 - Appareil et procede d'etanchement metal sur metal de puits de forage droit - Google Patents

Appareil et procede d'etanchement metal sur metal de puits de forage droit Download PDF

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Publication number
WO1994020728A1
WO1994020728A1 PCT/US1994/000181 US9400181W WO9420728A1 WO 1994020728 A1 WO1994020728 A1 WO 1994020728A1 US 9400181 W US9400181 W US 9400181W WO 9420728 A1 WO9420728 A1 WO 9420728A1
Authority
WO
WIPO (PCT)
Prior art keywords
metal
wellbore
sealing
sealing ring
tubular
Prior art date
Application number
PCT/US1994/000181
Other languages
English (en)
Inventor
John Lindley Baugh
George James Melenyzer
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to GB9420809A priority Critical patent/GB2281089A/en
Priority to AU62279/94A priority patent/AU6227994A/en
Publication of WO1994020728A1 publication Critical patent/WO1994020728A1/fr
Priority to NO19944192A priority patent/NO310373B1/no

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
    • E21B33/1216—Anti-extrusion means, e.g. means to prevent cold flow of rubber packing
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
    • E21B33/1212—Packers; Plugs characterised by the construction of the sealing or packing means including a metal-to-metal seal element
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/128—Packers; Plugs with a member expanded radially by axial pressure

Definitions

  • the present invention relates generally to metal-to-metal seals for use in oil and gas wellbores, and specifically to metal-to-metal seals which are run into the wellbore and set against wellbore surfaces.
  • Seals which include elastomeric components are subject to eventual deterioration after prolonged exposure to corrosive fluids and high temperatures. Also, when energized, elastomeric components are likely to flow along extrusion pathways if unchecked.
  • Metal components can be used to obtain gas tight seals, but are generally suited for rather pristine environments other than wellbores.
  • One problem with metal sealing components is that, like elastomeric components, metal sealing components will eventually become degraded after prolonged exposure to corrosive fluids.
  • a seal apparatus for use in a subterranean wellbore having a wellbore tubular disposed therein such as a casing string, which is of unknown condition.
  • the wellbore tubular defines a wellbore surface, which may have irregularities or defects therein such as nicks, cuts, grooves, gouged regions, corroded regions, and eccentricities and the like.
  • the wellbore tubular may have an inner diameter which varies over industry-accepted tolerance range; for example, a conventional casing tubular having a nine and five eighths (9 5/8) inches outer diameter may have a central bore with a diameter which is in the range of 8.379 to 8.670 inches, which represents an industry-accepted tolerance range for this type of tubular product.
  • the seal includes a number of components which cooperate together.
  • a conveyance tubular is provided, which is positionable within the subterranean wellbore at a selected location relative to the wellbore surface.
  • the conveyance tubular may comprise a workstring or a production string which may extend several thousand feet or more.
  • a sealing ring is provided, and disposed about at least a portion of the conveyance tubular.
  • the sealing ring has a first surface proximate the conveyance tubular and a second surface which is removed in distance from the conveyance tubular.
  • the second surface defines a sealing surface, and it includes a plurality of portions, with selected ones of the plurality of portions of the sealing ring extending radially from the conveyance tubular in at least one radial dimension.
  • the selected portions define at least one metal seal point for selectively and sealingly engaging the wellbore surface.
  • the seal apparatus is operable in a plurality of modes, including a running mode of operation and a sealing mode of operation.
  • the running mode of operation the sealing ring is maintained in a radially-reduced position, out of engagement with the wellbore surface.
  • the conveyance tubular may be run deep into the wellbore.
  • the sealing mode of operation the metal seal point of the sealing ring is in sealing metal-to-metal engagement with the wellbore surface of unknown, and in-fact unknowable condition, providing a fluid-tight seal at a selected location between the conveyance tubular and the wellbore tubular.
  • the seal apparatus of the present invention further includes an actuator member, which is selectively and remotely actuatable, for urging the sealing ring between the running and sealing modes of operation.
  • the actuator member is responsive to set down weight applied to the conveyance tubular string.
  • the inner surface of the wellbore tubular comprises the wellbore surface against which the seal operates
  • the first surface of the sealing ring comprises an inner surface which is proximate an outer surface of the conveyance tubular
  • the second surface of the sealing ring comprises an outer surface which sealingly engages the inner surface of the wellbore tubular during the sealing mode of operation.
  • the sealing ring will deform sufficiently to provide a gas-tight seal, even though the inner surface may have irregularities or defects thereon.
  • the inner surface of the sealing ring at least in-part defines a clearance which is between the sealing ring and the conveyance tubular.
  • the actuator member includes a wedge component which is driven into this cavity to selectively radially expand the sealing ring between the radially-reduced running mode of operation and the radially-expanded sealing mode of operation.
  • the sealing ring is radially expanded in shape by deformation through the wedging action of the actuator member.
  • the metal seal point of the sealing ring comprises at least one circumferential seal bead which is generally triangular in cross-section, and which is urged to engage the wellbore surface during the sealing mode of operation.
  • the metal seal points of the sealing ring are designed to be softer than the material which comprises the sealing surface, and thus will deform if sufficient force is applied to the sealing ring to expand it radially outward; in another embodiment, the metal seal points are formed of a material which is harder than the material which comprises the wellbore surface, and thus which will penetrate the wellbore surface if sufficient force is applied to outwardly radially expand the sealing ring.
  • the seal apparatus further includes a layer of resilient material disposed over at least a portion of the sealing surface of the sealing ring.
  • the layer of resilient material has an inner surface which is in engagement with the sealing surface of the sealing ring. Selected ones of the plurality of portions of the sealing ring extend radially outward and into the layer of resilient material, and are in gripping engagement therewith. These radially-extended portions prevent the layer of resilient material from swabbing-off during the running mode of operation.
  • the layer of resilient material includes an exterior surface of substantially uniform radial dimension, which sealingly engages the wellbore surface during the sealing mode of operation, in supplementation of the sealing engagement between the metal seal point and the wellbore surface.
  • the layer of resilient material further operates to prevent entrapment of wellbore fluids between selected ones of the metal seal points during the sealing mode of operation, while the seal points serve also to prevent extrusion of the layer of resilient material.
  • the portions of the sealing surface of the sealing ring which define the extender members extend into the layer of resilient material, and provide a skeletal structure (that is, a structural framework) for the layer of resilient material, to prevent swabbing-off of the layer of resilient material during the running mode of operation.
  • the plurality of extender members are oriented at selected angles relative to the sealing ring to counteract directional forces acting on the layer of resilient material during the running mode of operation.
  • the plurality of extender members include at least one extender member oriented generally outward and downward from the sealing surface of the sealing ring to counteract upward axial forces acting on the layer of resilient material during the running mode of operation, and at least one extender member oriented generally outward and upward from the sealing surface of the sealing ring to counteract downward axial forces acting on the layer of resilient material during the running mode of operation.
  • the inner surface of sealing ring at least in-part defines a cavity between the sealing ring and the conveyance tubular, which is generally triangular in cross-section.
  • the actuator member terminates at a wedge portion which is also generally triangular in cross-section, and which extends a selected distance into the cavity during the running mode of operation, but which is urged deeper in the cavity during the sealing mode of operation.
  • the sealing ring is formed of a selected material which yields to expand a selected distance relative to the conveyance tubular in response to insertion of the wedge portion into the cavity.
  • the actuator member includes an actuator sleeve which circumferentially engages the conveyance tubular, with the wedge ring coupled to the lowermost end of the actuator sleeve, and means for applying selected axial force to the actuator sleeve.
  • a locking mechanism is also provided in the preferred embodiment which allows only downward movement of the actuator sleeve relative to the conveyance tubular to prevent the metal-to-metal seal of the present invention from accidentally disengaging from the sealing mode of operation.
  • Figure 1 is a one-quarter longitudinal section view of the preferred embodiment of the seal apparatus of the present invention in a running mode of operation, disposed concentrically within a wellbore tubular;
  • Figure 2 is a one-quarter longitudinal section view of the preferred embodiment of the seal apparatus of the present invention in a sealing mode of operation, in sealing engagement with an interior surface of a wellbore tubular;
  • Figure 3a is a partial longitudinal section view of a prior art mandrel with an elastomeric outer layer disposed thereon;
  • Figure 3b is a partial longitudinal section view of a prior art mandrel with an elastomeric outer layer swabbing-off the mandrel in response to axial forces applied thereto;
  • Figure 4 is a partial longitudinal section view of the preferred seal apparatus of the present invention in a position intermediate that of the running and sealing modes of operations;
  • Figure 5 is a partial longitudinal section view of the preferred embodiment of the seal apparatus of the present invention in a sealing mode of operation
  • Figure 6 is a partial longitudinal section view of an alternative embodiment of the seal apparatus of the present invention in a sealing mode of operation
  • Figure 7 is a fragmentary longitudinal section view of the seal apparatus of the present invention, depicting the actuator linkage which allows a transfer of axial force in only one direction which serves to lock the seal apparatus in the sealing mode of operation in sealing engagement with the wellbore surface;
  • Figure 8 is a simplified partial longitudinal section view of the preferred seal apparatus of the present invention depicting the geometric configuration of the sealing surface of the sealing ring, which should be read with reference to Tables 1 and 2 which provide actual dimensions of the preferred embodiment;
  • Figures 9a, 9b, and 9c depict wellbore tubulars which are in poor conditions, and specifically depict tubulars which are (a) out-of-round, (b) include gouges, and (c) have corrosion damage; and
  • Figure 10 schematically depicts the utilization of the present invention to seal a region between a conveyance tubular and a wellbore tubular, which is of unknown condition.
  • Figure 1 is a one-quarter longitudinal section view of the preferred embodiment of the seal apparatus 11 of the present invention in a running mode of operation, and disposed concentrically within wellbore tubular 13.
  • Conveyance tubular 17 is preferably coupled to force transmitting sleeve 18 which is part of a tubular workstring (not depicted) which is used to lower conveyance tubular 17 to a selected location within wellbore 25 relative to tubular members 13.
  • seal apparatus 11 of the present invention may be conveyed via a tubular workstring to a remote wellbore location, many thousands of feet from the earth's surface, to a selected location within wellbore 25 relative to a tubular member 13, which has been maintained in wellbore 25 for a lengthy period of time, perhaps years, and which may be of an unknown, and unknowable, condition. Therefore, seal apparatus 11 has great utility in workover operations, wherein a wellbore is reengineered or reconditioned to enhance production. Typically, such workover operations are directed toward developing oil and gas production from one or more new production zones, and/or ceasing production from a previous production zone.
  • seal apparatus 11 Since seal apparatus 11 is intended to be conveyed many thousands of feet within a wellbore, through the central bore of a wellbore tubular which is of unknown condition, a substantial clearance must be provided to ensure that seal apparatus 11 does not become stuck during running-in operations. As is shown in Figure 1, seal apparatus 11 is adapted in radial dimension for passage through central bore 27 of tubular member 13. Seal apparatus 11 is depicted in Figure 1 in a radially-reduced running mode of operation, during which seal apparatus 11 is out of contact with wellbore surface 15 which defines central bore 27 of tubular member 13.
  • seal apparatus 11 In the event that seal apparatus 11 is run downward through the central bore of the casing string, at least three-sixteenths (3/16) of an inch of radial clearance is provided all the way around seal apparatus 11 to ensure that seal apparatus 11 does not become stuck within the casing string. If, for other applications, seal apparatus 11 is intended to be run through the central bore of a production tubing string, at least three-sixteenths (3/16) of an inch of radial clearance all the way around seal apparatus 11 would be required in order to prevent it from becoming stuck within the production string. In contrast, in Figure 2, seal apparatus 11 is shown in a radially-enlarged sealing mode of operation, in which components of seal apparatus 11 are in gas-tight sealing engagement with wellbore surface 15 of tubular member 13.
  • seal apparatus 11 may radially expand only a few thousandths of an inch or as great as three- sixteenths (3/16) to five-eighths (5/8) of an inch. In the embodiment described herein, such an expansion represents a five (5) to fifteen (15) percent expansion of the outward diameter of the metal ring portion of seal apparatus 11.
  • seal apparatus 11 of the preferred embodiment of the present invention includes sealing ring 19 which is circumferentially disposed about at least a portion of external surface 29 of conveyance tubular 17.
  • sealing ring 19 includes interior surface 31 and exterior surface 33, with interior surface 31 including upper portion 35 and lower portion 37, with upper portion 35 at least in-part defining an annular cavity 39 which extends circumferentially about external surface 29 of conveyance tubular 17 and sealing ring 19, and which is generally triangular in cross-section.
  • Interior surface 31 of sealing ring 19 further includes lower portion 37 which circumferentially engages external surface 29 of conveyance tubular 17.
  • actuator member 21 extends downward into annular cavity 39, and completely fills it.
  • Actuator member 21 includes conical wedge ring 41, force-transferring sleeve 18, and actuator linkage 43.
  • wedge ring 43 and force-transferring sleeve 18 are coupled by external threads 45 on the uppermost end of wedge ring 41 and by internal threads 47 at the lowermost end of force-transferring sleeve 18.
  • Actuator linkage 43 further includes ratchet ring 49 and retainer ring 51.
  • Ratchet ring 49 is annular in shape, and includes an interior surface upon which are disposed inwardly-facing ratchet teeth 53, which are machined in the "down" position.
  • inwardly-facing ratchet teeth 53 are adapted for engaging outwardly-facing ratchet teeth 55 which are circumferentially disposed along a portion of external surface 29 of conveyance tubular 17, and which are machined in the "up" position.
  • Ratchet teeth 55, 57 are adapted to allow only downward movement of ratchet ring 51 , and to oppose upward movement of ratchet ring 49 relative to conveyance tubular 17.
  • Figure 2 is a one-quarter longitudinal section view of the preferred embodiment of the seal apparatus 11 of the present invention in a sealing mode of operation, in sealing engagement with wellbore surface 15 of tubular member 13.
  • downward movement of force-transferring sleeve 18 will cause wedge ring 41 to be urged downward into annular cavity 39 which applies a radial force to sealing ring 19 causing the material which forms sealing ring 19 to deform by expanding radially outward and into contact with wellbore surface 15 of tubular member 13.
  • Downward movement of force-transferring sleeve 18 also causes ratchet ring 49 to travel downward along external surface 29 of conveyance tubular 17.
  • the orientation of ratchet teeth 53, 55 ensure that movement of ratchet ring 49 is limited to one direction, namely downward relative to conveyance tubular 17.
  • Sealing ring 19 is prevented from moving downward in response to downward displacement of force-transferring sleeve 18 by operation of buttress member 57 which is secured in a fixed position relative to conveyance tubular 17 by threaded coupling 63 and the mating of internal shoulder 59 of buttress member 57 and external shoulder 61 of conveyance tubular 17.
  • O-ring seal 65 which is disposed in O-ring cavity 67 at external surface 29 of conveyance tubular 17, which operates to provide a dynamic, gas-tight seal with interior surface 69 of force-transferring sleeve 18.
  • sealing ring 19 includes a layer of resilient material 71, which is in the preferred embodiment an elastomeric layer which is formed upon, or bonded, by conventional means, to exterior surface 33 of sealing ring 19.
  • Figures 3a and 3b are partial longitudinal section views of a prior art mandrel with an elastomeric outer layer disposed thereon, with Figure 3b depicting the swabbing-off of the elastomeric layer from the mandrel in response to axial forces applied thereto.
  • Figure 3a is a simplified depiction of a design which is common in wellbore completion equipment, in which elastomer band 72 is bonded to an exterior surface of mandrel 73 by use of adhesive 75 (which is not visible in either Figure 3a or 3b).
  • adhesive 75 which is not visible in either Figure 3a or 3b.
  • Fluid flow within the well in combination with the pressure differential created by the occlusion of a portion of the wellbore by mandrel 73 will create axial force 77 which may detach elastomer band 72 from mandrel 73, resulting in "swabbing-off" of elastomer band 72.
  • axial force 77 may detach elastomer band 72 from mandrel 73, resulting in "swabbing-off" of elastomer band 72.
  • the loss or displacement of elastomer band 72 could seriously impair the operation of a wellbore tool, which, for example, may be depending upon elastomer band 72 to supply a sealing engagement with other wellbore components.
  • Seal apparatus 11 of the present invention is designed to avoid the swabbing-off of a layer of resilient material 71, but also functions to provide a seal which combines many of the attractive features of metal-to-metal seals and elastomeric seals, as will be described now with reference to Figures 4
  • Figure 4 is a partial longitudinal section view of the preferred seal apparatus 11 of the present invention in a position intermediate that of the running and sealing modes of operations which are depicted in Figures 1 and 2.
  • Figure 5 is a partial longitudinal section view of the preferred embodiment of seal apparatus 11 of the present invention in a sealing mode of operation, in gas-tight and fluid-tight sealing engagement with wellbore surface 15 of tubular member 13.
  • wedge ring 41 includes inner surface 83 which slidably engages external surface 29 of conveyance tubular 17. The potential leak path at the interface of inner surface 83 and external surface 29 is sealed against leakage by operation of O-ring seal 81 which is disposed in O-ring cavity 79, which is formed in conveyance tubular 17 at external surface 29.
  • Wedge ring 41 further includes outer surface 85 which slidably engages interior surface 31 of sealing ring 19.
  • the potential leak path at the interface of interior surface 31 and outer surface 85 is sealed against fluid leakage by operation of O-ring seal 87 which is disposed in O-ring cavity 89 which is formed in sealing ring 19 at interior surface 31.
  • O-ring seal 87 provides a gas-tight and fluid-tight dynamic seal at the sliding interface of the surfaces.
  • wedge ring 41 includes outer surface 85 which is disposed at three (3) degrees of inclination from the longitudinal central axis of conveyance tubular 17.
  • sealing ring 19 includes raised portions 91, 93, 95, 97, 99, 101, and 103 which extend radially outward from the body portion 105 of sealing ring 19 a plurality of differing radial dimensions, and which define a plurality of extender members which extend from body portion 105, and which serve a variety of functions including: engaging in a metal-to-metal sealing engagement with wellbore surface 15, to provide back-up resilient seals which supplement the sealing action of the metal-to-metal seals, preventing the entrapment of corrosive or other wellbore fluids between selected metal seal points, and to provide a skeletal framework for a layer of resilient material 71 which extends over most of the exterior "sealing" surface 33 of sealing ring 19 and which prevents "swabbing-off" of the layer of resilient material 71 due to axial forces applied to the layer of resilient material 71 during the running mode of operation.
  • layer of resilient material 71 defines a substantially uniform sealing surface
  • Figures 5 and 6 depict, in partial longitudinal section view, two embodiments of the seal apparatus 11 of the present invention in sealing modes of operation.
  • the embodiment shown in Figure 5 is the preferred embodiment of the present invention, while the embodiment shown in Figure 6 is an alternative embodiment of the present invention. The differences between these embodiments is easily explained with reference to Figures 5 and 6.
  • metal seal points 109, 111, and 113 are composed of a material which is softer than the material which forms wellbore surface 15 of tubular member 13; therefore, the outermost extents (that is "tips") of metal seal points 109, 111, and 113 are blunted or slightly deformed after coming into engagement with wellbore surface 15 of tubular member 13. While blunted, they still provide a zero extrusion gap and a gas-tight seal between sealing ring 19 and wellbore surface 15 of tubular member 13.
  • metal seal points 115, 117, and 119 are composed of a material which is harder than that which forms wellbore surface 15 of tubular member 13; therefore, metal seal points 115, 117, and 119 will in fact penetrate the material which forms wellbore surface 15 of tubular member 13, also providing a zero extrusion gap for a gas-tight seal.
  • metal seal points 109, 111, 113 are formed of 1020 steel, which has a known, industry-standard modulus of elasticity and Poisson ratio; while tubular member 13, in one embodiment, may comprise a polished seal bore which is formed of 4140 steel.
  • metal seal points 115, 117, and 119 should be formed of a harder steel.
  • the seal apparatus 11 of the present invention may also function to provide a metal-to-metal sealing engagement with conventional wellbore tubulars, such as tubing and casing strings, which are for a particular well, of known hardness, but unknown condition, and may include nicks, gouges, and corroded regions or which may be out of round.
  • sealing ring 19 with layer of resilient material 71 disposed thereon, include providing a high quality, gas-tight metal-to-metal seal between sealing ring 19 and wellbore surface 15 of tubular member 13, providing a back-up resilient seal between the layer of resilient material 71 and wellbore surface 15 of tubular member 13, preventing the extrusion of portions of the layer of resilient material 71 from between selected metal seal points, and preventing the accumulation or entrapment of corrosive or other wellbore fluids around or between selected metal seal points.
  • wedge ring 41 As is shown in Figure 5, as wedge ring 41 is wedged downward into annular cavity 39, thicker portions of wedge ring 41 are urged between conveyance tubular 17 and sealing ring 19 (which are both stationary). Sealing ring 19 is maintained in a fixed position relative to both conveyance tubular 17 and tubular member 13 by operation of buttress member 57. Wedge ring 41 will apply a force to sealing ring 19 which includes both axial and radial force components. Force is provided to wedge ring 41 by conventional means, such as applying set down weight from a drilling or work-over rig to a workstring which includes force-translating sleeve 18. Alternately, the axial force can originate from conventional power charge setting tools.
  • the axial force component provided by wedge ring 41 serves to overcome the frictional resistance to the insertion of wedge ring 41 into annular cavity 39.
  • the radial force component (which is a sine function of the axial force component, and which depends upon the angle of inclination of outer surface 85 of wedge ring 41) serves to work against the material which comprises sealing ring 19, causing deformation of sealing ring 19 by outwardly radially expanding sealing ring 19 between the radially-reduced position of the running mode of operation and the radially-expanded position of the sealing mode of operation.
  • conveyance tubular 17 is formed of 4140 steel, having known and industry standard modulus of elasticity and Poisson ratio, in to the form of a cylinder having an outer diameter of 7 inches and an inner diameter of 6.25 inches.
  • sealing ring 19 is formed of 1020 steel. (The dimensions of the preferred sealing ring 19 of the present invention will be described in greater detail herebelow with reference to Figure 8.) Conveyance tubular 17 will not collapse or yield in response to radial force applied to sealing ring 19 by operation of wedge ring 41; instead, conveyance tubular 17 will provide a firm buttress to wedge ring 41.
  • sealing ring 19 will expand radially outward in response to the radial component of the axial force applied thereto by operation of wedge ring 41.
  • the operational result is that metal seal points 109, 111 , and 113 will be urged radially outward into engagement with wellbore surface 15 of tubular member 13.
  • metal seal points 109, 111, 113 are formed of a material comparable in hardness to wellbore surface 15, they will become blunted and deformed and may in-fact extend slightly into wellbore surface, yet will provide a gas-tight, extrusion resistant metal-to-metal seal with wellbore surface 15 of tubular member 13.
  • sealing ring 19 and layer of resilient material 71 are urged radially outward, wellbore fluids, including corrosive fluids, which would otherwise have been trapped between metal seal points 109, 111, and 113, are expelled by displacement either upward or downward relative to sealing ring 19.
  • the layer of resilient material 71 which in the preferred embodiment comprises an elastomeric band, will itself come into sealing engagement with wellbore surface 15 of tubular member 13, providing a back up seal to the seals provided by metal seal points 109, 111, and 113.
  • the sealing action of the layer of resilient material 71 can be quite good, provided wellbore temperatures in the vicinity of seal apparatus 11 are below 450 degrees Fahrenheit. Temperatures above 450 degrees Fahrenheit will quickly impair the sealing function of the layer of resilient material 71, which is preferably formed of an elastomeric material.
  • thermoplastic or other materials can be used to form the layer of resilient material 71 , which have still higher operating temperature ranges, and which are thus useful in wellbore regions which have temperatures which exceed 450 degrees Fahrenheit.
  • the sealing engagement between metal seal points 109, 111, and 113 also serve to provide an extrusion barrier to portions 121, 123 of the layer of resilient material 71 which is trapped between seal points 109, 111, 113 respectively.
  • portions 121, 123 serve primarily as a mechanism for evacuating wellbore fluids from between seal points 109, 111, 113; however, when temperatures encountered in the wellbore are within the range of operating temperatures associated with the material which comprises the layer of resilient material 71, portions 121, 123 serve as back-up elastomeric-type resilient seals, and cooperate with the metal-to-metal seals of metal seal points 109, 111, 113 and wellbore surface 15 of tubular member 13. As shown in Figure 5, at a low temperature range, seal apparatus 11 of the present invention provides three metal-to-metal seals and two resilient seals.
  • seal apparatus 11 may be run thousands of feet into a wellbore, during which wellbore fluids create axial forces which act upon the layer of resilient material 71 , and which tend to cause the material to swab-off.
  • the design and orientation of raised portions 91, 93, 95, 97, 99, 101, and 103 (of Figure 4) define a structural framework upon which the layer of resilient material 71 is formed or bonded, which deters and resists the axial forces which would otherwise urge the layer of resilient material 71 to swab-off sealing ring 19.
  • raised portions 91 , 103 provide a leading edge for sealing ring 19 which respectively shield the layer of resilient material 71 from axial forces encountered during downward and upward displacement within the wellbore.
  • Raised portion 93 defines an extender member which is oriented generally outward and upward from the sealing surface 33 of sealing ring 19, which extends into the layer of resilient material 71, and counteracts or resists downward axial forces acting on the layer of resilient material 71 during the running mode of operation.
  • raised portion 101 defines an extender member which is oriented generally outward and downward from sealing surface 33 of sealing ring 19, which extends into the layer of resilient material 71 , and which resists or counteracts upward axial forces acting on the layer of resilient material 71.
  • the raised shoulder defined by raised portion 95 extends into the layer of resilient material 71, and is oriented generally outward and upward from the sealing surface 33 of sealing ring 19, to resist or counteract downward axial forces acting on the layer of resilient material 71.
  • the shoulder defined by raised portion 99 extends into the layer of resilient material 71 and is oriented generally outward and downward from sealing surface 33 of sealing ring 19, and serves to resist or counteract upward axial forces acting on the layer of resilient material 17 during the running mode of operation.
  • Raised portion 97 defines an extender member which is oriented directly radially outward, and which is thus equally resistive to both upward and downward axial forces, and cannot be considered a directional-specific extender member. In this manner, raised portions 91, 93, 95, 97, 99, 101, and 103 cooperate together to minimize the opportunity for swabbing-off of the layer of resilient material 71 from sealing surface 33 of sealing ring 19.
  • Figure 8 is a cross-section view of sealing ring 19 of the preferred embodiment of the present invention, and is used to provide a precise physical description of the various components which together comprise sealing ring 19.
  • Physical dimensions, including distances and angles are indicated on the figure by single letters for length and width dimensions, and double letters for angles.
  • lateral dimension lines on Figure 8 indicate diameter of the portion, unless specifically indicated otherwise.
  • the letter “L” indicates the outer diameter from the outermost radial surface of raised portion 103 of sealing ring 19.
  • Other measurements, such as "I” indicate the distance between the dimension lines which are provided as an overlay on the cross-section view of sealing ring 19. Length and width dimensions are provided in Table 1 , and angle measurements are provided in Table 2.
  • seal apparatus 11 has an outer diameter of 8.210 inches, and an inner diameter which ranges from 7.45 inches to 7.780 inches, and which is thus suited for conveyance into a wellbore on a conveyance tubular which has an outer diameter of 7.45 inches or less.
  • Figure 8 depicts seal apparatus 11 in an undeformed condition.
  • outward radial deformation is expected to be in the range of three-sixteenths (3/16) to five-sixteenths (5/16) of an inch, to close an expected clearance between the outer diameter of seal apparatus 11 and an adjoining wellbore tubular, such as a casing string, which in this case, will have an outer diameter of nine and five-eights (9 5/8) inches, and an inner diameter somewhere in the acceptable range of 8.379 inches to 8.670 inches.
  • the wellbore tubular may have been in the wellbore for an extended period of time, and thus exposed to corrosive wellbore fluids, high temperatures, high pressures, and may have been subjected to mechanical damage during the running in or out of other wellbore tools.
  • the wellbore tubular 13 may include substantial defects, such as an eccentric (out-of-round) central bore, which is depicted in Figure 9a, a gouge or nick, such as depicted in Figure 9b, or a corroded surface, such as depicted in Figure 9c.
  • seal apparatus 11 may be designed to seal against different sizes of tubular products, including other sizes of casing. Conventional casing ranges in outer diameter from four inches to sixteen inches.
  • Seal apparatus 11 would be scaled upward or downward to allow (1) a running clearance between the seal apparatus 11 and the wellbore tubular of about three-sixteenths of an inch all the way around seal apparatus 11 , and (2) radial expansion of the metal ring component of seal apparatus 11 which is at least large enough to span the running clearance.
  • Such expansion can be as small as a few thousandths of an inch to as much as fifteen percent (15%) of the outer diameter of the metal ring component of seal apparatus 11.
  • the metal ring component of seal apparatus 11 will be expanded radially in an amount which is in the range of five percent to fifteen percent (5% -15%) of the outer diameter of the metal ring component.
  • seal apparatus 11 may operate to provide a gas-tight, metal-to-meal seal with a wellbore tubular of (1) unknown condition and/or (2) unknown inner diameter.
  • the present invention allows for a high-integrity, and long-service-life seal with tubulars of a wide range of conditions and a wide range of diameter sizes.
  • the condition and size of the wellbore tubular need not be known or investigated; this is a significant benefit since it may be impossible to know the condition or exact inner diameter of remotely-located, permanently placed wellbore tubulars.
  • Figure 7 is a fragmentary longitudinal section view of a portion of seal apparatus 11 of the present invention, depicting actuator linkage 43 which allows a transfer of axial force in only one direction to urge the seal apparatus 11 into sealing engagement with wellbore surface 15.
  • Actuator linkage 43 was discussed above generally in connection with Figure 2.
  • external threads 131 of the upper portion of wedge ring 41 engage internal threads 133 of the lowermost portion of force-transferring sleeve 18.
  • Wedge ring 41 includes interior inclined surface 135 which engages exterior inclined surface of ratchet ring 49.
  • Ratchet ring 49 includes inwardly-facing ratchet teeth 53 which engage outwardly facing ratchet teeth 55 of conveyance tubular 17, as axial force 139 is applied to force-transferring sleeve 18.
  • Retaining ring 51 comprises, in the preferred embodiment, a snap ring.
  • O-ring 141 is disposed between retainer ring 51 and ratchet ring 49 and functions as a rubber spring to hold the retainer
  • Actuator linkage 43 of the present invention operates to lock wedge ring 41 in a fixed position relative to sealing ring 19 once the sealing mode of operation of obtained. This ensures that the metal-to-metal seal obtained by seal apparatus 11 of the present invention is permanently energized and maintained in the sealing mode of operation to prevent accidental, or unintentional, release of the sealing engagement between sealing ring 19 and wellbore surface 15 of tubular member 13.
  • the present invention may also be characterized as a method of sealing in a wellbore having a tubular member disposed therein which defines a wellbore surface.
  • the method includes steps of providing a metal conveyance tubular with a cylindrical outer surface, and providing a metal sealing ring with at least one circular metal extender portion extending radially outward from the outer surface of the metal sealing ring.
  • the metal sealing ring should also be provided with a contoured inner surface.
  • the metal sealing ring is placed around the metal conveyance tubular so that the contoured inner surface at least in-part defines an annular cavity around the metal conveyance tubular.
  • a metal conical wedge ring is provided which has a sloped outer surface. The metal conical wedge ring is placed around the metal conveyance tubular and disposed at least in-part within the annular cavity between the metal conveyance tubular and the metal sealing ring.
  • the metal conveyance tubular, metal sealing ring, and metal conical wedge ring are lowered into the wellbore to a desired location within the central bore of the tubular member. Then, an axial load is applied to the metal conical wedge ring to drive it between the metal conveyance tubular and the metal sealing ring, causing the metal sealing ring to deform by expanding radially outward. At least one circular metal extender portion which is disposed on the outermost surface of the metal seal ring is urged into sealing metal-to-metal engagement with the wellbore surface of the tubular member.
  • the annular region which is defined between the conveyance tubular and the tubular member is occluded by a gas-tight barrier which is composed substantially entirely of metal components. Since the sealing barrier is composed of metal, preferably steel, the metal-to-metal seal apparatus of the present invention can provide a seal which can withstand extremely high pressure differentials, as opposed to conventional seals which form an annular barrier which at least in-part includes substantial elastomeric components.
  • Figure 10 is a simplified schematic view of utilization of work-over rig 201 to create and lower production string 203 within wellbore 215.
  • work-over rig 201 includes conventional hoisting equipment 207 for raising and lowering production string 203 within wellbore 215, power tongs 205 for making-up and breaking-down the production tubing string, as needed, and gripping equipment 209 which 1 serves to engage production string 203 during make-up operations.
  • wellbore 215 includes casing string 213 with interior surface 211 which defines a central bore.
  • casing 213 may have been installed within wellbore 215 many years prior to the workover operation, and may be composed of a known grade of steel, which is in an unknown, and quite possibly unknowable condition, and may include nicks, cuts, gouges, corroded regions, and out-of-round regions. Additionally, casing 213 may have an inner diameter which is within a range of acceptable inner diameter for particular casing type and size. As is shown, seal apparatus 11 may be aligned next to a particular region 219 of wellbore 215 which may have these and other defects in the interior surface which defines the central bore. Region 219 may be located several hundred or several thousand feet from work-over rig 201.
  • seal apparatus 11 is utilized to seal annular region 217 between production string 203 and casing 213, notwithstanding the fact that region 219 of casing 213 may have many of the above-identified defects which would normally pose a severe problem for sealing operations.
  • seal apparatus 11 has a sufficiently small radial dimension during running operations to pass through hundreds or thousands of feet of wellbore without becoming stuck, but expands radially outward in an amount which is sufficient to forcefully engage region 219 of casing 213 in a manner which either (1) deforms selected ones of the raised portions, or (2) urges selected ones of the raised portions to penetrate into casing 213 at region 219, to provide a gas-tight, metal-to-metal seal which effectively seals annular region 217.
  • the metal-to-metal seal apparatus of the present invention can withstand pressure differentials of between 10,000 and 16,000 pounds per square inch, at extremely high temperatures. It is believed that the metal-to-metal seal of the present invention can provide a gas-tight barrier to pressure differentials of 20,000 pounds per square inch or greater. It can thus be appreciated that the seal apparatus and method of the present invention can provide a high quality, gas-tight sealing engagement, which may find many commercial uses in wellbore drilling and completion operations.
  • the present invention represents a significant advance over prior art devices.
  • the clearance provided around the seal apparatus which can be identified as the "running clearance,” is sufficiently large to allow the seal apparatus to be run into remote locations within a wellbore which may be thousands and thousands of feet away from the earth's surface.
  • the seal apparatus is then subjected to a large amount of force, causing the metal ring component of the seal apparatus to deform radially outward to span the running clearance between the seal apparatus and a remotely-located wellbore tubular member.
  • the radial running clearance between the seal apparatus and the wellbore tubular is approximately three-sixteenths (3/16) of an inch.
  • the outward radial expansion of the metal ring component of the seal apparatus can be only a few thousandths of an inch, or as great as three-sixteenths (3/16) of an inch to five-sixteenths (5/16) of an inch.
  • the wellbore tubular may have nicks, gouges, corroded regions, or irregularities in the shape of the inner bore. Furthermore, even if the wellbore tubular is not damaged in any respect, it may have an inner diameter which falls within an industry-accepted range of acceptable inner diameters. The variance of the inner diameters of undamaged tubulars spans a significant distance range.
  • the present invention provides a seal apparatus which will provide a gas-tight, long-service-life, metal-to-metal wellbore seal which will seal against the wellbore tubular, irrespective of the actual inner diameter of the wellbore tubular, provided it is within the total expansion range of the metal seal component of the wellbore tubular.
  • expansion of the metal seal component can represent a five to fifteen percent (5%-15%) radial expansion of the metal ring component. Although greater percentages of expansion are possible, particularly if different materials are selected to form the metal ring component, in the present invention the amount of radial expansion must be at least as great as the running clearance between the seal apparatus and the wellbore tubular against which it is intended to seal. In the embodiment described herein, radial expansion can be as large as five-sixteenths (5/16) of an inch, which exceeds the preferred running clearance between the seal apparatus and the wellbore tubular by two-sixteenths (2/16) of an inch. This significant range of possible maximum expansion of the metal ring component allows the seal apparatus to seal against wellbore tubulars which have significant damage, shape irregularities, and inner diameter dimensions.
  • the running clearance is completely spanned by expansion of the ring, but an additional sixty to seventy percent of the running clearance may also be spanned.
  • This allows for tight seals against seriously damaged or deformed wellbore tubulars, without requiring the operator to determine the condition of the tubular or dimensions of such tubulars.
  • the operator need only have knowledge of the "nominal" (that is, the stated) dimension of the wellbore tubular. For example, engineering records of a particular well may indicate that nine and five-eights (9 5/8) inches outer diameter casing is disposed at a region of interest within the wellbore.
  • the operator may select a seal apparatus in accordance with the present invention which is sized and constructed to allow for unobstructed running-in operations through all intermediate tubulars between the surface and the nine and five-eights ( 9 5/8) inches casing. Furthermore, the selected seal apparatus will be capable of sufficient outward radial expansion to engage the nine and five-eights inches casing in a gas-tight seal, even though the inner diameter of the casing varies over an acceptable range, or includes deformities or damage such as corroded regions, gouges, nicks and eccentricities.
  • the significant range of possible expansions of the metal ring component of the seal apparatus ensures that a great number of types of deformities and irregularities, as well as a great range in degree of deformities and irregularities, may be effectively sealed by the present invention.
  • the present invention may be sized upward or downward to allow for running-in operations through either production tubing or casing, as long as a sufficient running clearance is provided between the tool and the tubular strings between the earth's surface and the desired setting location. All that is further required is that the metal ring component of the apparatus be expandable to an extent which is sufficient to entirely bridge the running clearance, and preferably additional clearance which may be provided by gouges, nicks, corroded regions, eccentricities, or variance of the inner diameter within an acceptable range of diameters.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Gasket Seals (AREA)
  • Sealing Devices (AREA)

Abstract

L'invention concerne un appareil d'étanchement destiné à être utilisé dans un puits de forage souterrain dans lequel est placé un tubage (13). Ledit tubage définit une surface de puits de forage (27). L'appareil d'étanchement comporte plusieurs composants coopérant les uns avec les autres. Un tubage de transport (17) est placé dans le puits de forage souterrain en un point sélectionné par rapport à la surface du puits. Un anneau d'étanchéité (19) placé autour d'au moins une partie du tubage de transport présente une première surface (31) à proximité du tubage de transport, et une deuxième surface (33) éloignée de ce dernier. La deuxième surface définit une surface d'étanchement et comporte une pluralité d'éléments dont certains sélectionnés (91, 93, 95, 97, 99, 101, 103) s'étendent radialement depuis le tubage de transport dans au moins une dimension radiale. Lesdits éléments sélectionnés définissent au moins un point d'étanchement métallique destiné à venir en contact de manière sélective étanche avec la surface du puits. L'appareil d'étanchement peut fonctionner selon une pluralité de modes, dont un mode de déplacement et un mode d'étanchement. Dans le mode de déplacement, l'anneau d'étanchéité est maintenu dans une position radialement réduite et n'est pas en contact avec la surface du puits. Dans le mode d'étanchement, au moins un point d'étanchement de l'anneau d'étanchéité est en contact d'étanchement métal sur métal avec la surface du puits de manière à assurer une étanchéité en un point sélectionné entre le tubage de transport et le tubage du puits de forage. L'appareil d'étanchement selon l'invention présente également un élément actionneur (21) commandé à distance et sélectivement permettant de faire passer l'anneau d'étanchéité du mode de déplacement au mode d'étanchement et vice-versa.
PCT/US1994/000181 1993-03-04 1994-03-02 Appareil et procede d'etanchement metal sur metal de puits de forage droit WO1994020728A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
GB9420809A GB2281089A (en) 1993-03-04 1994-03-02 Straight bore metal-to-metal wellbore seal apparatus and method of sealing in a well-bore
AU62279/94A AU6227994A (en) 1993-03-04 1994-03-02 Straight bore metal-to-metal wellbore seal apparatus and method of sealing in a wellbore
NO19944192A NO310373B1 (no) 1993-03-04 1994-11-03 Rettlinjet, metallisk borehull-tetningsanordning og fremgangsmåte for tetting i et borehull

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US2636593A 1993-03-04 1993-03-04
US08/026,365 1993-03-04

Publications (1)

Publication Number Publication Date
WO1994020728A1 true WO1994020728A1 (fr) 1994-09-15

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Country Status (5)

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AU (1) AU6227994A (fr)
CA (1) CA2134762C (fr)
GB (1) GB2281089A (fr)
NO (1) NO310373B1 (fr)
WO (1) WO1994020728A1 (fr)

Cited By (1)

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Publication number Priority date Publication date Assignee Title
EP2952672A1 (fr) * 2014-06-04 2015-12-09 Welltec A/S Tubulaire métallique expansible de fond

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2329388C (fr) * 1999-12-22 2008-03-18 Smith International, Inc. Appareil et methode de mise en place ou d'ancrage d'un tube dans un autre tube

Citations (7)

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US4302018A (en) * 1980-02-29 1981-11-24 Foster-Miller Associates, Inc. Packer arrangements for oil wells and the like
US4588029A (en) * 1984-09-27 1986-05-13 Camco, Incorporated Expandable metal seal for a well tool
US4719971A (en) * 1986-08-18 1988-01-19 Vetco Gray Inc. Metal-to-metal/elastomeric pack-off assembly for subsea wellhead systems
US4749035A (en) * 1987-04-30 1988-06-07 Cameron Iron Works Usa, Inc. Tubing packer
US4790572A (en) * 1987-12-28 1988-12-13 Vetco Gray Inc. Tapered wedge packoff assembly for a casing hanger
US4901794A (en) * 1989-01-23 1990-02-20 Baker Hughes Incorporated Subterranean well anchoring apparatus
WO1993015304A1 (fr) * 1992-01-29 1993-08-05 Baker Hughes Incorporated Appareil obturateur de puits de forage metal-metal a alesage droit et procede d'obturation d'un puits de forage

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4302018A (en) * 1980-02-29 1981-11-24 Foster-Miller Associates, Inc. Packer arrangements for oil wells and the like
US4588029A (en) * 1984-09-27 1986-05-13 Camco, Incorporated Expandable metal seal for a well tool
US4719971A (en) * 1986-08-18 1988-01-19 Vetco Gray Inc. Metal-to-metal/elastomeric pack-off assembly for subsea wellhead systems
US4749035A (en) * 1987-04-30 1988-06-07 Cameron Iron Works Usa, Inc. Tubing packer
US4790572A (en) * 1987-12-28 1988-12-13 Vetco Gray Inc. Tapered wedge packoff assembly for a casing hanger
US4901794A (en) * 1989-01-23 1990-02-20 Baker Hughes Incorporated Subterranean well anchoring apparatus
WO1993015304A1 (fr) * 1992-01-29 1993-08-05 Baker Hughes Incorporated Appareil obturateur de puits de forage metal-metal a alesage droit et procede d'obturation d'un puits de forage

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2952672A1 (fr) * 2014-06-04 2015-12-09 Welltec A/S Tubulaire métallique expansible de fond
WO2015185683A1 (fr) * 2014-06-04 2015-12-10 Welltec A/S Tubulaire métallique extensible de fond de trou
US10711559B2 (en) 2014-06-04 2020-07-14 Welltec Oilfield Solutions Ag Downhole expandable metal tubular
US11473392B2 (en) 2014-06-04 2022-10-18 Welltec Oilfield Solutions Ag Downhole expandable metal tubular

Also Published As

Publication number Publication date
AU6227994A (en) 1994-09-26
CA2134762C (fr) 1997-12-30
NO310373B1 (no) 2001-06-25
CA2134762A1 (fr) 1994-09-15
NO944192D0 (no) 1994-11-03
NO944192L (no) 1995-01-03
GB9420809D0 (en) 1994-11-30
GB2281089A (en) 1995-02-22

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