EP2995768B1 - Dispositif de prévention d'évacuation avec lame comprenant de multiples profils - Google Patents

Dispositif de prévention d'évacuation avec lame comprenant de multiples profils Download PDF

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Publication number
EP2995768B1
EP2995768B1 EP14306403.8A EP14306403A EP2995768B1 EP 2995768 B1 EP2995768 B1 EP 2995768B1 EP 14306403 A EP14306403 A EP 14306403A EP 2995768 B1 EP2995768 B1 EP 2995768B1
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EP
European Patent Office
Prior art keywords
blade
tubular
blowout preventer
cutting profile
shear
Prior art date
Legal status (The legal status 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 status listed.)
Active
Application number
EP14306403.8A
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German (de)
English (en)
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EP2995768A1 (fr
Inventor
Florent Vargas
Pascal Berthaud
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Cameron Technologies Ltd
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Cameron Technologies Ltd
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 Cameron Technologies Ltd filed Critical Cameron Technologies Ltd
Priority to EP14306403.8A priority Critical patent/EP2995768B1/fr
Priority to US14/443,536 priority patent/US20160258238A1/en
Priority to PCT/US2015/030132 priority patent/WO2016039823A1/fr
Publication of EP2995768A1 publication Critical patent/EP2995768A1/fr
Application granted granted Critical
Publication of EP2995768B1 publication Critical patent/EP2995768B1/fr
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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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • E21B33/061—Ram-type blow-out preventers, e.g. with pivoting rams
    • E21B33/062—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams
    • E21B33/063—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams for shearing drill pipes

Definitions

  • Blowout preventers are used extensively throughout the oil and gas industry. Typical blowout preventers are used as a large specialized valve or similar mechanical device that seal, control, and monitor oil and gas wells. The two categories of blowout preventers that are most prevalent are ram blowout preventers and annular blowout preventers. Blowout preventer stacks frequently utilize both types, typically with at least one annular blowout preventer stacked above several ram blowout preventers. The ram units in ram blowout preventers allow for both the shearing of the drill pipe and the sealing of the blowout preventer. Typically, a blowout preventer stack may be secured to a wellhead and may provide a safe means for sealing the well in the event of a system failure.
  • a ram bonnet assembly may be bolted to the main body using a number of high tensile bolts or studs. These bolts are required to hold the bonnet in position to enable the sealing arrangements to work effectively.
  • an elastomeric sealing element is used between the ram bonnet and the main body. There are several configurations, but essentially they are all directed to preventing a leakage bypass between the mating faces of the ram bonnet and the main body.
  • blowout preventers may be subject to pressures up to 138000 kPa (20,000 psi), or even higher. To be able to operate against and to contain fluids at such pressures, blowout preventers are becoming larger and stronger. Blowout preventer stacks, including related devices, 9.1 meters (30 feet) or more in height are increasingly common.
  • ram-type blowout preventers may be designed and constructed for use with drill pipe or other tubulars of specified diameter.
  • a blowout preventer stack including rams for one size of pipe may be used with pipe of a different size by changing the pipe engaging rams or parts of the rams.
  • the ram operating mechanisms in a blowout preventer are comparatively complex and require inspection and servicing before the blowout preventer is put into service at a wellhead. Such activities, when performed in a large modern blowout preventer stack, may require the presence of personnel at locations that can be hazardous, if not impractical.
  • Document EP2484860 A2 discloses a pair of shear blades and a blowout preventer having the pair of shear blades.
  • the shear blades are configured to cut a tubular inside the blowout preventer.
  • the shear blades have different geometries of the front cutting surfaces. One geometry promotes a secure positioning of the tubular relative to the first blade while the second geometry promotes a puncturing of the tubular by the second blade.
  • Document US2007/0246215 A1 discloses methods and apparatuses for severing a wellbore tubular, the apparatus, in certain aspects, including: a first member movable toward a tubular to be severed; a second member with a second blade disposed opposite to the first member and movable toward the tubular; a first blade on the first member having a projection projecting from a center of a blade body with point structure on the projection for puncturing the tubular and cutting surfaces on the projection for cutting the tubular; and cutting surfaces, as needed, on the blade body adjacent the projection for cutting the tubular.
  • Document US2011/0226477 discloses a method for severing a tubular of a wellbore.
  • the method involves positioning a blowout preventer about a tubular, the blowout preventer having a plurality of rams slidably positionable therein and a plurality of blades carried by the rams for engaging the tubular.
  • the method further involves piercing the tubular with a piercing point of at least one of the blades such that a portion of the tubular is dislodged therefrom, and raking through the tubular with a cutting surface of at least one of the blades.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to... .”
  • the term “couple” or “couples” is intended to mean either an indirect or direct connection.
  • the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis.
  • an axial distance refers to a distance measured along or parallel to the central axis
  • a radial distance means a distance measured perpendicular to the central axis.
  • top,” “bottom,” “above,” “below,” and variations of these terms is made for convenience, but does not require any particular orientation of the components.
  • the blowout preventer 10 which may be referred to as a ram blowout preventer, includes a body 12 with a vertical bore 14 formed and/or extending through the body 12. As shown, the body 12 may include a lower flange 16 and/or an upper flange 18, such as to facilitate connecting the blowout preventer 10 to other blowout preventers and/or other components. Cavities and/or guideways 20 and 22 may be formed within the body 12 of the blowout preventer 10, in which the guideways 20 and 22 may extend outwardly from the bore 14 and/or be formed on opposite sides of the bore 14.
  • the blowout preventer 10 may then include one or more ram assemblies, such as a first ram 24 and a second ram 26.
  • the first ram 24 may be positioned and movable within the first guideway 20 and a second ram 26 positioned and movable within the second guideway 22, such as by having the first ram 24 and/or the second ram 26 movable towards and away from the tubular D.
  • One or more actuators 28 may be provided to move the first ram 24 and/or the second ram 26, such as for moving the first ram 24 and/or the second ram 26 into the bore 14 to shear the portion of the tubular D extending through the bore 14 of the blowout preventer 10.
  • a hydraulic actuator is shown, though any type of actuator (e.g., pneumatic, electrical, mechanical) may be used in accordance with the present disclosure.
  • the actuators 28 shown in this embodiment may include a piston 30 positioned within a cylinder 32 and a rod 34 connecting the piston 30 to each respective ram 24 and 26. Further, pressurized fluid may be introduced and fluidly communicated on opposite sides of the piston 30 through ports 35, thereby enabling the actuator 28 to move the rams 24 and 26 in response to fluid pressure.
  • a first (e.g., upper) blade 36 (any blade according to the present disclosure) may be included with or connected to the first ram 24, and a second (e.g., lower) blade 38 (any blade according to the present disclosure) may be included with or connected to the second ram 26.
  • the first and second blades 36 and 38 may be formed and positioned such that a cutting edge of the second blade 38 passes below a cutting edge of the first blade 36 in shearing of a section of a tubular D.
  • the shearing action of first and second blades 36 and 38 may shear the tubular D.
  • the lower portion of the tubular D may then drop into the well bore (not shown) below the blowout preventer 10, or the tubular D may hung off a lower set of rams (not shown).
  • a system blowout preventer, and/or a blade for a blowout preventer for shearing a tubular.
  • the tubular may be positioned within the bore extending through the blowout preventer, in which the blowout preventer may be actuated to move one or more blades to engage and shear the tubular.
  • a blade of a blowout preventer in accordance with the present disclosure may be used for shearing one or more different types of tubulars that may have different shapes, sizes, thicknesses, and other dimensions and properties.
  • a tubular may include a drill pipe joint, a casing joint, and/or a tool joint, in which a blowout preventer in accordance with the present disclosure may be used to shear each of these different types of tubulars. These tubulars may be sheared with or without replacement of any blade of the blowout preventer.
  • a blowout preventer 200 may include a first (e.g., upper) shear ram 202A and a second (e.g., lower) shear ram 202B, in which the first shear ram 202A and/or the second shear ram 202B may be movable towards and/or away a bore of the blowout preventer, such as for shearing a tubular positioned within the bore of the blowout preventer.
  • FIG. 2A shows an above perspective view of the first shear ram 202A and the second shear ram 202B
  • FIG. 2B shows a below perspective view of the first shear ram 202A and the second shear ram 202B
  • FIG. 2C shows an above view of the first shear ram 202A and the second shear ram 202B fully retracted with a full bore 290.
  • a blowout preventer in accordance with the present disclosure may be used for shearing one or more different tubulars. As such, FIG.
  • FIG. 2D shows an above view of the first shear ram 202A and the second shear ram 202B moved towards a casing joint 292A for engaging and shearing the casing joint 292A
  • FIG. 2E shows an above view of the first shear ram 202A and the second shear ram 202B moved towards a tool joint 292B for engaging and shearing the tool joint 292B
  • FIG. 2F shows an above view of the first shear ram 202A and the second shear ram 202B moved towards a drill pipe joint 292C for engaging and shearing the drill pipe joint 292C
  • FIG. 2G shows an above view of the first shear ram 202A and the second shear ram 202B fully closed, such as after shearing a tubular.
  • the first shear ram 202A includes a first blade 204A
  • the second shear ram 202B includes a second blade 204B.
  • the blades 204A and 204B may be formed integrally with the shear rams 202A and 202B.
  • the blades 504A and 504B may be formed integrally with the shear rams 502A and 502B.
  • the blades 204A and 204B, or at least a portion thereof, may be replaceable with respect to the shear rams 202A and 202B.
  • the first shear ram 202A may include a slot 206A formed therein, in which an insert 208A including the first blade 204A may be inserted into the slot 206A to be removably connected to (e.g., replaceable within) the first shear ram 202A.
  • the second shear ram 202B may include a slot 206B formed therein, in which an insert 208B including the second blade 204B may be inserted into the slot 206B to be removably connected to (e.g., replaceable within) the second shear ram 202B.
  • a blade in accordance with the present disclosure may include one or more cutting profiles formed thereon or included therewith.
  • the first blade 204A may include an outer cutting profile 210A and an inner cutting profile 212A.
  • the inner cutting profile 212A may be positioned within or between portions of the outer cutting profile 210A.
  • the outer cutting profile 210A may include a first blade portion 214A and a second blade portion 216A, in which the inner cutting profile 212A is positioned between the blade portions 214A and 216A such that the blade portions 214A and 216A are positioned on opposite sides of the inner cutting profile 212A.
  • the second blade 204B may include an outer cutting profile 210B and an inner cutting profile 212B.
  • the inner cutting profile 212B may be positioned within or between portions of the outer cutting profile 210B.
  • the outer cutting profile 210B may include a first (e.g., third overall) blade portion 214B and a second (e.g., fourth overall) blade portion 216B, in which the inner cutting profile 212B is positioned between the blade portions 214B and 216B such that the blade portions 214B and 216B are positioned on opposite sides of the inner cutting profile 212B.
  • a blade in accordance with the present disclosure may be used within a shear ram of a blowout preventer, such as to shear one or more different types of tubulars with the blowout preventer.
  • a blade in accordance with the present disclosure may be designed to reduce stress concentrations to facilitate this shearing action.
  • blade portions of an outer cutting profile may be positioned at least about 120 degrees from each other.
  • the blade portions 214A and 216A of the outer cutting profile 210A of the first blade 204A may be positioned at least about 120 degrees from each other. More particularly, the blade portions 214A and 216A may be positioned between about 120 degrees and about 140 degrees from each other, if not positioned at about 120 degrees from each other.
  • the blade portions 214B and 216B of the outer cutting profile 210B of the second blade 204B may be positioned at least about 120 degrees from each other. More particularly, the blade portions 214B and 216B may be positioned between about 120 degrees and about 140 degrees from each other, if not positioned at about 120 degrees from each other.
  • Such a configuration may enable the outer cutting profiles 210A and 210B of the blades 204A and 204B to have a V-profile.
  • the inner cutting profile 212A for the first blade 204A and/or the inner cutting profile 212B for the second blade 204B may be sized to reduce stress concentrations, such as when engaging or shearing a tubular having a particular size or strength.
  • the tool joint 292B may have the largest thickness, compared to the casing joint 292A shown in FIG. 2D and the drill pipe joint 292C shown in FIG. 2F .
  • the inner cutting profiles 212A and 212B may be sized to engage and shear the tool joint 292B.
  • an outer diameter of a standard tool joint may be about 21.6 cm (8.5 inches)
  • a diameter of the inner cutting profiles 212A and 212B may also be about 21.6 cm (8.5 inches).
  • an inner cutting profile of a blade in accordance with the present disclosure may be formed to complement the outer profile of the tool joint. This may enable substantially all or the entirety of the inner cutting profile of the blade to engage the tool joint, such as to maximize contact with the tool joint for purposes of shearing.
  • the first shear ram 202A may include a mud slot 220A, such as formed on a bottom surface thereof, and the second shear ram 202B may include a mud slot 220B, such as also formed on a bottom surface thereof.
  • the mud slots 220A and 220B may be used to accommodate the flow of mud and fluid around the shear rams 202A and 202B, particularly when the shear rams 202A and 202B have been at least partially moved into the bore 290.
  • first shear ram 202A may include an actuator slot 222A, such as formed on a surface of the first shear ram 202A opposite the first blade 204A
  • second shear ram 202B may include an actuator slot 222B, such as formed on a surface of the second shear ram 202B opposite the second blade 204B.
  • the actuator slots 222A and 222B may be used to engage with an actuator, such as a rod 34 (shown in FIGS. 1A-1C ), to move the shear rams 202A and 202B into and out of the bore 290.
  • FIGS. 3A-3G multiple views of a first shear ram 302A and a second shear ram 302B for a blowout preventer to shear a tubular in accordance with the present disclosure are shown.
  • FIGS. 3A and 3B show perspective views of the shear rams 302A and 302B
  • FIG. 3C shows an above view of the shear rams 302A and 302B fully retracted from a full bore 390.
  • FIG. 3D shows an above view of the shear rams 302A and 302B moved towards a casing joint 392A for engaging and shearing the casing joint 392A
  • FIG. 3E shows an above view of the shear rams 302A and 302B moved towards a tool joint 392B for engaging and shearing the tool joint 392B
  • FIG. 3F shows an above view of the shear rams 302A and 302B moved towards a drill pipe joint 392C for engaging and shearing the drill pipe joint 392C
  • FIG. 3G shows an above view of the shear rams 302A and 302B fully closed, such as after shearing a tubular.
  • the first shear ram 302A includes a first blade 304A, in which, in this embodiment, an insert 308A including the first blade 304A may be inserted into the slot 306A to be removably connected to (e.g., replaceable within) the first shear ram 302A.
  • the second shear ram 302B includes a second blade 304B, in which an insert 308B including the second blade 304B may be inserted into the slot 306B to be removably connected to (e.g., replaceable within) the second shear ram 302B.
  • the first blade 304A may include an outer cutting profile 310A and an inner cutting profile 312A, in which the outer cutting profile 310A may include a first blade portion 314A and a second blade portion 316A and be similar to an outer cutting profile described above.
  • the second blade 304B may include an outer cutting profile 310B and an inner cutting profile 312B, in which the outer cutting profile 310B may include a first blade portion 314B and a second blade portion 316B and be similar to an outer cutting profile described above.
  • an inner cutting profile in accordance with the present disclosure may be sized and/or shaped to reduce stress concentrations on the blades and/or increase the stress on the tubular when shearing.
  • an inner cutting profile in accordance with the present disclosure may include one or more projections, such as to define one or more initial contact points between a blade and a tubular as the blade moves towards the tubular for shearing. In particular, this may define an initial contact point for the inner cutting profile and/or the blade altogether when contacting and engaging the tubular as a shear ram closes and a blade moves towards the tubular for shearing.
  • the inner cutting profile 312A of the first blade 304A may include a first projection 324A and a second projection 326A, in which the first projection 324A and/or the second projection 326A may be used to define an initial contact point between the first blade 304A and a tubular (depending on the size and shape of the tubular, as shown in FIGS. 3D-3G ).
  • the inner cutting profile 312B of the second blade 304B may include a first (e.g., third) projection 324B and a second (e.g., fourth) projection 326B, in which the first projection 324B and/or the second projection 326B may be used to define an initial contact point between the second blade 304B and a tubular.
  • a first (e.g., third) projection 324B and a second (e.g., fourth) projection 326B in which the first projection 324B and/or the second projection 326B may be used to define an initial contact point between the second blade 304B and a tubular.
  • Such a configuration may enable the inner cutting profiles 310A and 310B of the blades 304A and 304B to have a dual indenter-profile.
  • a dual indenter-profile of a blade in accordance with the present disclosure may facilitate centralizing and/or stabilizing a tubular member, independent of size (e.g., a tool joint, a drill pipe joint, and/or a casing joint), when also shearing the tubular member with the blade.
  • a tubular member independent of size (e.g., a tool joint, a drill pipe joint, and/or a casing joint)
  • one or more of the projections of the blades of the shear rams may include a radiused edge, such as to reduce stress concentrations at the projection.
  • each of the projections 324A, 324B, 326A, and 326B may include a radiused edge, in which the projections 324A, 324B, 326A, and 326B may be rounded at an end thereof, such as to prevent damage to the blades 304A and 304B.
  • FIGS. 4A-4G multiple views of a first shear ram 402A and a second shear ram 402B for a blowout preventer to shear a tubular in accordance with the present disclosure are shown.
  • FIGS. 4A and 4B show perspective views of the shear rams 402A and 402B
  • FIG. 4C shows an above view of the shear rams 402A and 402B fully retracted from a full bore 490.
  • FIG. 4D shows an above view of the shear rams 402A and 402B moved towards a casing joint 492A for engaging and shearing the casing joint 492A
  • FIG. 4E shows an above view of the shear rams 402A and 402B moved towards a tool joint 492B for engaging and shearing the tool joint 492B
  • FIG. 4F shows an above view of the shear rams 402A and 402B moved towards a drill pipe joint 492C for engaging and shearing the drill pipe joint 492C
  • FIG. 4G shows an above view of the shear rams 402A and 402B fully closed, such as after shearing a tubular.
  • the first shear ram 402A includes a first blade 404A, in which, in this embodiment, an insert 408A including the first blade 404A may be inserted into the slot 406A to be removably connected to (e.g., replaceable within) the first shear ram 402A.
  • the second shear ram 402B includes a second blade 404B, in which an insert 408B including the second blade 404B may be inserted into the slot 406B to be removably connected to (e.g., replaceable within) the second shear ram 402B.
  • the first blade 404A may include an outer cutting profile 410A and an inner cutting profile 412A, in which the outer cutting profile 410A may include a first blade portion 414A and a second blade portion 416A and be similar to an outer cutting profile described above.
  • the second blade 404B may include an outer cutting profile 410B and an inner cutting profile 412B, in which the outer cutting profile 410B may include a first blade portion 414B and a second blade portion 416B and be similar to an outer cutting profile described above.
  • an inner cutting profile in accordance with the present disclosure may include one or more projections.
  • the inner cutting profile 412A of the first blade 404A may include a first projection 424A, a second projection 426A, and a third projection 428A.
  • the first projection 424A, the second projection 426A, and/or the third projection 428A may be used to define an initial contact point between the first blade 404A and a tubular (depending on the size and shape of the tubular, as shown in FIGS. 4D-4G ).
  • the inner cutting profile 412B of the second blade 404B may include a first (e.g., fourth) projection 424B, a second (e.g., fifth) projection 426B, and a third (e.g., sixth) projection 428B.
  • the first projection 424B, the second projection 426B, and/or the third projection 428B may be used to define an initial contact point between the second blade 404B and a tubular.
  • Such a configuration may enable the inner cutting profiles 410A and 410B of the blades 404A and 404B to have a triple indenter-profile.
  • a triple indenter-profile of a blade in accordance with the present disclosure may facilitate centralizing and/or stabilizing a tubular member, independent of size (e.g., a tool joint, a drill pipe joint, and/or a casing joint), when also shearing the tubular member with the blade.
  • a tubular member independent of size (e.g., a tool joint, a drill pipe joint, and/or a casing joint)
  • an inner cutting profile of a blade may include more than two projections
  • the projections e.g., edges, tips, and/or contact points of the projections
  • the projections may be positioned on a radius, diameter, and/or an arc with respect to each other.
  • an outer diameter of a standard tool joint may be about 21.6 cm (8.5 in)
  • a diameter for the positions of the tips of the projections 424A, 426A, and 428A of the first blade 404A and/or for the positions of the tips of the projections 424B, 426B, and 428B of the second blade 404B may also be about 21.6 cm (8.5 in).
  • blades 404A may be able to define similar initial contact points between the projections 424A, 424B, 426A, 426B, 428A, and 428B and a tubular having a similar diameter when shearing the tubular.
  • Those having ordinary skill in the art will appreciate that other sizes, configurations, and diameters may be used for an inner cutting profile, in addition to an outer cutting profile, without departing from the scope of the present disclosure.
  • a blade in accordance with the present disclosure may be symmetrical.
  • a line of symmetry may extend through an inner cutting profile of a blade.
  • the above embodiments show profiles matching between each of the first blades and the second blades, the present disclosure is not so limited.
  • other blades or blade profiles may be used with a blade or blade profile identified above within one or more embodiments.
  • the first blade may or may not be identical to the second blade, such as depending on the application.
  • a blade and a blowout preventer in accordance with the present disclosure may be used to shear one or more tubulars, including a casing joint, a drill pipe joint, and a tool joint, with each having various shapes, sizes, and/or other dimensions.
  • a casing joint may have one or more sizes, such as an outer diameter of about 40.6 cm (16 in), about 35.6 cm (14 in, about 30.5 cm (12 in), and/or about 26.99cm (10.625 in)
  • a drill pipe joint may have one or more sizes, such as an outer diameter of about 16.83cm (6.625 in), about 14.0 cm (5.5 in), and/or about 8.9 cm (3.5 in).
  • one or more blades, shear rams, and/or blowout preventers in accordance with the present disclosure may be used to shear one or more different tubulars and/or different sizes or dimensions of tubulars.
  • a blade in accordance with the present disclosure may be replaceable, one or more blades of a blowout preventer may be replaced based upon the tubular. For example, if the blowout preventer is used to shear a tool joint, one or both blades of the blowout preventer may be replaced to have an inner cutting profile (with or without projections) with a diameter similar to that of the tool joint. Replacement may involve replacing the blade only, as an insert may include the blade, or may involve replacing at least a portion of the blade or replacing the shear ram that includes the blade.

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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)
  • Shearing Machines (AREA)

Claims (12)

  1. Bloc obturateur de puits (200) destiné à cisailler un élément tubulaire positionné dans un trou s'étendant à travers le bloc obturateur de puits (200), le bloc obturateur de puits (200) comprenant :
    une première mâchoire de sécurité à cisaillement (202A) pouvant être déplacée vers l'élément tubulaire, la première mâchoire de sécurité à cisaillement (202A) comprenant une première lame (204A), la première lame (204A) comprenant un premier profil de coupe extérieur (210A) formé à partir des première et deuxième parties de lame extérieure (214A ; 216A) et un premier profil de coupe intérieur (212A) ; et
    une deuxième mâchoire de sécurité à cisaillement (202B) positionnée en regard de la première mâchoire de sécurité à cisaillement (202A) par rapport à l'élément tubulaire et pouvant être déplacée vers l'élément tubulaire, la deuxième mâchoire de sécurité à cisaillement (202B) comprenant une deuxième lame (204B), la deuxième lame (204B) comprenant un deuxième profil de coupe extérieur (210B) formé à partir des troisième et quatrième parties de lame extérieure (214B ; 216B) et un deuxième profil de coupe intérieur (212B) ;
    dans lequel pour chacune des première et deuxième lames (204A ; 204B), les parties de lame extérieure du profil de coupe extérieur sont positionnées sur les côtés opposés du profil de coupe intérieur (212A) et caractérisées en ce que les parties de lame extérieure sont positionnées entre un angle d'environ 120 degrés et un angle d'environ 140 degrés l'une de l'autre ; et
    dans lequel un diamètre des profils de coupe intérieurs (212A, 212B) est similaire à celui d'un raccord d'outil de l'élément tubulaire.
  2. Bloc obturateur de puits selon la revendication 1, comprenant en outre :
    un premier insert (208A) pouvant être raccordé de manière amovible à la première mâchoire de sécurité à cisaillement (202A) ;
    dans lequel le premier insert (208A) comprend au moins une partie de la première lame (204A).
  3. Bloc obturateur de puits selon la revendication 1 ou 2, dans lequel la première partie de lame (214A) et la deuxième partie de lame (214A ; 216A) des profils de coupe extérieurs (210A ; 210B) sont positionnées à un angle d'environ 120 degrés l'une de l'autre.
  4. Bloc obturateur de puits selon l'une quelconque des revendications précédentes, dans lequel les profils de coupe extérieurs (210A ; 210B) comprennent un profil en V.
  5. Bloc obturateur de puits selon l'une quelconque des revendications précédentes, dans lequel le profil de coupe intérieur (212A ; 212B) présente un diamètre d'environ 21,6 cm (8,5 pouces).
  6. Bloc obturateur de puits selon la revendication 1, dans lequel les profils de coupe intérieurs (212A ; 212B) comprennent chacun au moins une projection (324A ; 324B) pour définir un point de contact initial des première et deuxième lames (204A ; 204B) avec l'élément tubulaire lorsque les première et deuxième mâchoires de sécurité à cisaillement se déplacent vers l'élément tubulaire.
  7. Bloc obturateur de puits selon la revendication 6, dans lequel le profil de coupe intérieur comprend une première projection (424A) et une deuxième projection (426A), de sorte qu'au moins l'une parmi la première projection et la deuxième projection définit le point de contact initial des première et deuxième lames avec l'élément tubulaire.
  8. Bloc obturateur de puits selon la revendication 7, dans lequel le profil de coupe intérieur comprend en outre une troisième projection (428A), dans lequel les pointes de la première projection, de la deuxième projection et de la troisième projection sont positionnées sur le diamètre du profil intérieur l'une par rapport à l'autre.
  9. Bloc obturateur de puits selon l'une quelconque des revendications précédentes, dans lequel les première et deuxième lames (204A ; 204B) sont symétriques de sorte qu'une ligne de symétrie s'étend à travers le profil de coupe intérieur (212A) de la première lame (204A).
  10. Bloc obturateur de puits selon l'une quelconque des revendications précédentes, dans lequel ledit élément tubulaire comprend en outre une pluralité d'éléments tubulaires comprenant un raccord de tige de forage, un raccord de tubage et un raccord d'outil de sorte que le bloc obturateur de puits (200) est conçu pour cisailler chaque raccord parmi le raccord de tige de forage, le raccord de tubage et le raccord d'outil.
  11. Procédé destiné à actionner un bloc obturateur de puits pour cisailler un élément tubulaire à l'intérieur du bloc obturateur de puits, comprenant :
    le déplacement d'une première lame (204A) comprenant un premier profil de coupe extérieur (210A) et un premier profil de coupe intérieur (212A) vers l'élément tubulaire, le premier profil de coupe extérieur (210A) comprenant une première partie de lame (214A) et une deuxième partie de lame (216A), chacune sur les côtés opposés du premier profil de coupe intérieur (212A) et positionnées entre un angle d'environ 120 degrés et un angle d'environ 140 degrés l'une de l'autre, dans lequel le premier profil de coupe intérieur (212A) comprend au moins deux projections (324A ; 324B) avec extrémités arrondies pour définir les points de contact initiaux de la première lame (204A) avec l'élément tubulaire;
    le déplacement d'un deuxième lame (204B) comprenant un deuxième profil de coupe extérieur (210B) et un deuxième profil de coupe intérieur (212B) vers l'élément tubulaire dans le bloc obturateur de puits, le deuxième profil de coupe extérieur (210B) comprenant une troisième partie de lame (214B) et une quatrième partie de lame (216B), chacune sur les côtés opposés du deuxième profil de coupe intérieur (212B) et positionnées entre un angle d'environ 120 degrés et un angle d'environ 140 degrés l'une de l'autre, dans lequel un diamètre des profils de coupe intérieurs (212A, 212B) est similaire à celui d'un raccord d'outil de l'élément tubulaire ; et
    le cisaillement de l'élément tubulaire avec la première lame et la deuxième lame (204B).
  12. Procédé selon la revendication 11, dans lequel l'élément tubulaire comprend en outre une pluralité d'éléments tubulaires comprenant un raccord de tige de forage, un raccord de tubage et un raccord d'outil dans lequel le cisaillement de l'élément tubulaire comprend au moins l'un parmi :
    le cisaillement du raccord de tige de forage en déplaçant la première lame et la deuxième lame vers le raccord de tige de forage ;
    le cisaillement du raccord de tubage en déplaçant la première lame et la deuxième lame vers le raccord de tubage ; et le cisaillement du raccord d'outil en déplaçant la première lame et la deuxième lame vers le raccord d'outil.
EP14306403.8A 2014-09-12 2014-09-12 Dispositif de prévention d'évacuation avec lame comprenant de multiples profils Active EP2995768B1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP14306403.8A EP2995768B1 (fr) 2014-09-12 2014-09-12 Dispositif de prévention d'évacuation avec lame comprenant de multiples profils
US14/443,536 US20160258238A1 (en) 2014-09-12 2015-05-11 Blowout Preventer with Blade Including Multiple Profiles
PCT/US2015/030132 WO2016039823A1 (fr) 2014-09-12 2015-05-11 Bloc obturateur de puits ayant une lame comprenant des profils multiples

Applications Claiming Priority (1)

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EP14306403.8A EP2995768B1 (fr) 2014-09-12 2014-09-12 Dispositif de prévention d'évacuation avec lame comprenant de multiples profils

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GB201614712D0 (en) 2016-08-31 2016-10-12 Enovate Systems Ltd Improved shear blade
WO2020219137A1 (fr) * 2019-04-21 2020-10-29 Cameron International Corporation Bloc d'obturation de puits doté de lames de mâchoire à application multiple
US11286740B2 (en) 2019-04-21 2022-03-29 Schlumberger Technology Corporation Blowout preventer shearing ram
WO2020219410A1 (fr) * 2019-04-21 2020-10-29 Cameron International Corporation Mâchoire à cisaillement de bloc d'obturation de puits
USD973734S1 (en) * 2019-08-06 2022-12-27 Nxl Technologies Inc. Blind shear
US11391108B2 (en) 2020-06-03 2022-07-19 Schlumberger Technology Corporation Shear ram for a blowout preventer
IT202000022756A1 (it) * 2020-09-28 2022-03-28 Eni Spa Valvola e metodo per la chiusura di pozzi estrattivi in condizioni di emergenza.

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EP2995768A1 (fr) 2016-03-16
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