EP1370745B1 - Procede et dispositif de separation de tiges faites d'elements tubulaires emboites - Google Patents

Procede et dispositif de separation de tiges faites d'elements tubulaires emboites Download PDF

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Publication number
EP1370745B1
EP1370745B1 EP02720112A EP02720112A EP1370745B1 EP 1370745 B1 EP1370745 B1 EP 1370745B1 EP 02720112 A EP02720112 A EP 02720112A EP 02720112 A EP02720112 A EP 02720112A EP 1370745 B1 EP1370745 B1 EP 1370745B1
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EP
European Patent Office
Prior art keywords
casing
assembly
blade
clamp
housing
Prior art date
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Expired - Lifetime
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EP02720112A
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German (de)
English (en)
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EP1370745A2 (fr
Inventor
Richard Patrick Harding
Per Fotland
Tor Jan Akerlund
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Weatherford Lamb Inc
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Weatherford Lamb Inc
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Publication of EP1370745A2 publication Critical patent/EP1370745A2/fr
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00—Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground

Definitions

  • the present invention generally relates to plugging and abandonment of oil and gas wells. More particularly, the present invention relates to the removal of a tubular from a wellbore in order to satisfy various environmental regulations. More particularly still, the invention relates to severing nested strings of tubulars that are cemented together in order to more easily handle the tubulars as they are removed from a wellbore during or subsequent to a plugging and abandonment operation.
  • boreholes are formed in the earth and thereafter are lined with steel pipe known as casing.
  • An annular area formed between the outside of the casing and the wall of the borehole is typically filled with cement in order to secure the casing in the borehole and to facilitate the isolation of certain areas of the wellbore for the collection of hydrocarbons.
  • concentric strings of tubulars are disposed in the wellbore with each lower string of tubulars being necessarily smaller in diameter than the previous string. In some cases, especially in offshore oil and gas wells, the strings are run in a nested fashion from the surface of the well.
  • a first string of casing is cemented into the wellbore and, subsequently, a second smaller string of casing is cemented into the first string to permit the borehole to be lined to a greater depth.
  • This process is typically repeated with additional casing strings until the well has been drilled to total depth.
  • wells are typically formed with two or more strings of casing of an ever-decreasing diameter.
  • the severed upper string of casing includes more than one set of tubulars.
  • the outer casing string is 13 3/8 inches (34 cm) in diameter, and the smaller casing nested therein is 9 5/8 inches (24.4 cm) in diameter.
  • a casing string is typically comprised of a series of joints that are 30 feet (9.1 m) in length.
  • the pipe joints are connected by threaded male-to-female connections.
  • this process is difficult where the severed string consists of outer and inner pipe strings cemented together.
  • the severed casing is typically broken into smaller joints by cutting through the inner and outer strings at the surface of the well. The severed pipe sections are then recycled or otherwise disposed of.
  • casing strings are severed generally as follows:
  • the casing string is severed within the wellbore. Typically, severance is accomplished at a depth of around 1,000 feet (305 m). Thereafter, the severed portion of casing is "jacked" out of the wellbore and raised to the surface of the rig platform using a platform-mounted elevator. As the upper end of the severed casing section reaches the floor of the platform, it is lifted to a predetermined height above a set of slips. The slips are then set, suspending the severed string of casing above the rig floor. A drilling machine then drills a hole completely through the casing, including any cement layer and smaller diameter casing which is cemented within the larger diameter casing.
  • a band saw is used to cut the severed tubular into a predetermined length.
  • the band saw operates with coolant to avoid the use of high temperature cutters or the production of sparks.
  • a length of approximately ten feet (3 m) is selected, with the cut being made above the retention pin.
  • the newly severed, ten-foot (3 m) portion of string is then transported to a barge or other transportation means for disposal or salvage.
  • the elevator With the slips disengaged, the elevator then raises the severed string of casing another length of approximately ten feet (3 m). The slips are then re-engaged and the drilling, anchoring and cutting procedure takes place again.
  • GB-A-2313859 describes an apparatus for severing a riser of a sub-sea well following abandonment of the well.
  • a horizontal hole is formed through the riser and a pin inserted through that hole.
  • the riser is then raised ten metres, and a clamp ring fitted around the riser and slips.
  • a guillotine is then used to sever the riser.
  • an apparatus for severing casing above a wellbore comprising:
  • the apparatus comprises:
  • the present invention generally provides an apparatus and method for severing predetermined lengths of nested casing above a drilling rig or workover rig platform.
  • the apparatus includes a clamp assembly, a drill assembly and a cutting assembly.
  • the clamp assembly, the drilling assembly and the cutting assembly are disposed at the end of a telescopic arm, and are remotely operated by personnel using a control panel.
  • the clamp assembly is positioned adjacent a section of casing to be severed, and then clamped thereto.
  • the drilling assembly is actuated so as to drill a hole completely through the casing strings.
  • a retention pin is then inserted through the newly formed aperture.
  • the cutting assembly such as a band saw, is actuated so as to severe the casing above the pin.
  • the newly severed portion of casing above the pin may then be disposed of.
  • Figure 1 provides a perspective view of a tubular cutting apparatus 100.
  • the apparatus 100 comprises a clamp assembly 130, a drill assembly 150 and a cutting assembly 120.
  • the apparatus 100 is selectively movable.
  • the apparatus 100 is disposed at the end of an extendable structure.
  • the extendable structure is shown as a cantilevered arm 110.
  • the exemplary arm 110 defines an outer barrel 110 having at least one telescoping section 112 extending therefrom.
  • An intermediate telescoping section (not shown) may also be incorporated.
  • the end telescoping section 112 is slidably mounted in the intermediate telescoping section which is, in turn, slidably mounted in the outer barrel 110.
  • the arm 110 is supported by a base 114 secured to the floor of a rig platform (not shown).
  • the arm 110 is disposed on a vertical support beam 116 vertically extending above the base 114.
  • the outer barrel of the arm 110 may be attached to the support beam 116 by means of a clamp (not shown in Figure 1) bolted to the top of the beam 116.
  • a suitable clamp is shown for example in WO 98/32947, incorporated herein by reference, with reference to a telescopic arm for supporting a tong. The clamp maintains the arm 110 in position with respect to the beam 116.
  • the arm 110 is pivotally attached to the support beam 116 to permit the tubular severing apparatus 100 to pivot about a vertical axis and, alternatively or in addition, a horizontal axis.
  • the clamp is releasably attached to the support beam 116.
  • an additional feature of the arm 110 is that the outer barrel 110 of the arm itself may be selectively moved with respect to the support beam 116. This means that the entire arm 110 may be retracted away from the casing section 200'. When the telescoping sections 112 are fully contracted, the free end of the arm 110 lies closely adjacent the support beam 116.
  • This retracting feature is shown in Figure 4 of the WO 98/32947, incorporated herein by reference, with respect to a tong, but may also be employed in the present application with respect to a tubular severing assembly 100.
  • the apparatus 100 is further supported by an overhead hoisting system. Cables 160 from the hoisting system are visible in Figure 1.
  • the hoisting system maneuvers the tubular severing apparatus 100, with the telescoping section 112 of the arm 110 moving in response.
  • the telescoping section 112 of the arm 110 is hydraulically powered, causing the apparatus 100 and the supporting cables 160 to advance and recede in response to movement of the arm 110.
  • the arm 110 and the hoisting system may be independently powered.
  • casing section 200' represents an upper, severed string of casing that is being retrieved from a wellbore (not shown in Figure 1).
  • the casing 200' is being further severed into smaller portions for ease of manipulation and disposal.
  • the exemplary casing string 200' houses a smaller, inner string of casing 205 nested within an outer casing string 200.
  • the inner string 205 has been cemented into the outer string 200 in connection with earlier wellbore completion operations.
  • Figure 2 is a schematic view of the apparatus 100, adjacent a section of casing 200'. Visible again in Figure 2 is the clamp assembly 130, the drill assembly 150 and the cutting assembly 120. In this arrangement, the assembly 100 is again disposed at the distal end of the telescopic arm 110 and is suspended from above with cables 160.
  • the telescopic arm 110 again has at least one telescoping section 112.
  • the clamp assembly 130 is radially disposed about the section of casing 200' so as to secure the casing section 200' for severing.
  • the casing 200' is shown in Figure 2 in cross-section. Visible in this view are the outer casing string 200, the inner casing string 205 and a matrix of cured cement 210 in the annular region between the two casing strings 200, 205.
  • FIG 3 is a perspective view showing a cross-section of the casing 200' after it has been severed using the apparatus 100 of Figure 2.
  • casing section 200' defines an outer string of casing 200 which houses a smaller diameter casing 205.
  • a matrix of cement 210 is disposed in an annular area between the two casing strings 200, 205.
  • inner casing string 205 is eccentric relative to the surrounding outer casing string 200, as is typical in a completed wellbore.
  • the tubular string 200' is shown being held above a floor member 170 by a set of slips 172.
  • the slips 172 permit the tubular string 200' to be raised from below the surface of the platform to some height.
  • elevators are provided on a rig for maneuvering pipe relative to the wellbore.
  • the slips 172 hold the casing 200' so that it can be clamped and severed by the apparatus 100 after positioning of the casing 200' by the elevators.
  • the apparatus 100 includes a drill assembly 150.
  • the purpose of the drill assembly 150 is to form an aperture through the casing strings 200, 205 for insertion of a retention member 165.
  • the retention member 165 defines a pin configured to be received within the formed aperture.
  • Various pin types may be used, including, for example, a cylindrical bar, a cotter pin, or a cotter and key.
  • a simple tubular pin is shown.
  • the pin 165 serves to anchor any nested casing string 205 and cement 210 to the outer casing string 200.
  • the aperture is formed completely through both the front and back walls of the outer casing string 200, and the pin 165 is inserted completely through the outer casing string 200.
  • the drill assembly 150 is disposed below the band saw 120.
  • the drill assembly 150 is constructed and arranged to insert a rotating drill bit 151 essentially perpendicular to the longitudinal axis of the casing string 200'. In this way, a suitable aperture is formed. Any known drilling device may be employed for boring a through-opening into the casing section 200'.
  • the drill assembly 150 of Figure 2 utilizes a rotary motor (not shown) inside of a housing 153 to rotate a single drill bit 151.
  • a positioning device is further provided for selectively advancing the drill bit 151 towards and away from the casing section 200.
  • FIG. 4 An enlarged perspective view of a drill assembly 150 in operation is shown in Figure 4.
  • the drill bit 151 can be more clearly seen penetrating the wall of the outer section of casing 200.
  • the drill assembly 150 typically operates with a source of coolant and advances forward towards the casing 200 by means of a telescoping positioning device, shown in FIG. 4 as a cylinder 156.
  • the drill assembly 150 is operated remotely from a control panel 125 as is shown in Figure 2.
  • the remote control panel 125 will be more fully described, infra.
  • Figures 5a and 5b An alternative arrangement for a drill assembly is presented in Figures 5a and 5b.
  • Figure 5a is a top view of the alternative drilling assembly.
  • Figure 5b is a side view thereof.
  • a pair of opposing boring devices 155 are urged inwardly towards the center of the casing section 200'.
  • Any drilling assembly 150 capable of boring an aperture through the casing section 200' for insertion of an anchoring pin 165 may be employed.
  • the drill assembly 150 has been actuated to form an aperture through both casings strings 200, 205.
  • the pin 165 has been inserted through the formed aperture to anchor the inner casing 205 to the outer casing 200.
  • FIG. 6 is a perspective view of the apparatus 100 of Figure 1.
  • the clamp assembly 130 includes a frame 134 that selectively radially encompasses the casing section 200' in order to secure the apparatus 100 to the casing section 200'.
  • the clamp assembly 130 further comprises at least two clamp members 140 for frictionally engaging the casing 200'.
  • the clamp members 140 each define a pair of angled support blocks which are moved into contact with the casing 200'.
  • other arrangements may be employed, such as a single block having a concave surface.
  • the clamp assembly 130 includes a gate member 135 that swivels about a hinge 133 mounted on the frame 134.
  • the hinge 133 permits the gate member 135 to be selectively opened and closed for receiving and for clamping the casing 200'.
  • the gate member 135 is closed about the casing 200' while the casing section 200' is being severed.
  • the gate member 135 includes at least one clamp member 140 for engaging the casing 200' in its closed position.
  • the gate 135 preferably operated with hydraulic power, and is remotely operated from control panel 125.
  • a hydraulic arm 136 is shown to aid in remotely opening and closing the gate 135.
  • FIG 7 presents the apparatus 100 of Figure 1 in still greater detail.
  • the cutting assembly 120 is more clearly seen.
  • the cutting assembly 120 is shown as a band saw.
  • the band saw 120 first comprises a housing 122.
  • the housing 122 houses a pair of wheels (not seen in Figure 7) about which a band saw blade 121 is tracked.
  • the band saw blade 121 includes a plurality of teeth.
  • the blade 121 is fed through pairs of roller members 123 which guide the blade 121 to cut in a direction substantially perpendicular to the longitudinal axis of the outer casing 200.
  • One pair of roller members 123 is preferably provided at the housing outlet for the blade 121. In this respect, the blade 121 is fed through this first pair of roller members 123.
  • a second pair of roller members 123 is disposed at the opening in the housing 122 through which the blade 121 is received back into the housing 122.
  • the roller members 123 are more clearly seen in the enlarged view of Figure 8.
  • any cutting device 120 known for severing casing may be used, so long as the cutting device 120 may be adapted to operate in conjunction with a clamp assembly 130 and a drill assembly 150.
  • the cutting assembly defines a band saw 120.
  • the band saw 120 includes a housing 122 that is offset from the angle of cutting by the blade 121.
  • the angle of the housing 122 of the band saw 120 is offset from the angle at which the teeth of the blade 121 engage the outer casing 200 during the cutting operation.
  • the angle shown is approximately 30 degrees, though other angles may be used.
  • an enlarged spacing 129 is provided in the housing 122 between the wheels.
  • the blade 121 of the band saw 120 has been actuated.
  • the blade 121 is engaging the casing section 200', and has advanced partway through the casing 200' to form a cut that is substantially perpendicular to the longitudinal axis of the outer casing 200.
  • the band saw 120, the clamp assembly 130, and the drill assembly 150 are preferably controlled in an automated fashion from a control panel 125.
  • Control lines 126 are provided from the control panel 125 to control the assembly 100, e.g., parts 120, 130, 150, 154, etc..
  • Figure 9 is a more detailed perspective view showing a typical control panel 125 to be utilized with a tubular severing apparatus 100.
  • the illustrated control panel 125 in one aspect includes separate controls to operate the clamp assembly 130, the drilling assembly 150, and the band saw 120.
  • the band saw 120 and the drill assembly 150 are typically operated with similar controls.
  • the drill assembly 150 and saw 120 each require an on/off control and a rotational speed control to manipulate the rotation of the saw blade 121 or the drill bit 151.
  • Corresponding gauges illustrating the rotational movement of the drill bit 151 and the band saw 121 as shown in revolutions per minute may optionally be provided.
  • a tool advancing control is provided to control the speed of advance of the drill bit 151 into the casing 200' and the blade 121 of the band saw 120 into the casing 200'.
  • Corresponding positioning devices 126 shown in FIG. 1) and 156 (shown in FIG. 4) are provided for the band saw 121 and the drill assembly 150. These devices permit the drill bit 151 of the drill assembly 150 and the blade 121 of the band saw 120 to be independently, selectively advanced towards the casing 200' during the respective drilling and cutting operations and then withdrawn.
  • both the band saw 120 and the drill assembly 150 optionally include pressure sensors to determine the amount of pressure placed upon the casing by the rotating drill bit 151 or the rotating saw blade 121.
  • Gauges may be provided at the control panel 125 indicating pressures on the drill bit 151 or the rotating saw blade 121.
  • the clamp assembly 130 also has controls that are located on the control panel 125.
  • the clamp assembly 130 includes a panel-mounted control which opens and closes the gate 135 located on the clamp assembly 130.
  • a gauge indicating pressure between the casing 200' and a clamp 140 may be provided and pressure of the clamps 140.
  • a corresponding sensor is positioned on at least one of the clamp members 140 for sensing pressure of the clamp member 140 against the casing 200 when the gate 135 is closed.
  • the sensor is placed on the clamp member 140 on the gate 135.
  • the severing apparatus of the present invention operates as follows:
  • a casing cutting means (not shown) is run into a wellbore.
  • the cutting means is typically disposed on the end of a run-in string or wireline.
  • the cutting means is placed in the wellbore at a predetermined depth, and then actuated. In this way, a selected length of casing is severed downhole. Thereafter, the severed portion of casing 200 is pulled or "jacked out" of the wellbore and lifted to the rig platform within an elevator.
  • a predetermined amount of the severed portion of casing 200' is pulled upwards past the slip 172 located at the level of the platform floor.
  • the casing 200' is held in place by the slip 172, exposing the upper portion of the casing 200' above the platform floor.
  • a tubular severing apparatus 100 is moved towards the casing 200' by the telescopic arm assembly 110 with its extending and retracting sections 112.
  • the clamp assembly 130 is actuated to open the gate 135 and to receive the casing 200'.
  • the gate 135 is then closed around the casing 200', and the clamp assembly 130 is secured to the casing 200' by the clamping members 140. In this way, the severing apparatus 100 is properly positioned with respect to the casing 200'.
  • the drill assembly 150 is operated.
  • remote actuation of the drill assembly 150 is conducted through the control panel 125.
  • the drill bit 151 disposed on the drill assembly 150 is rotated and advanced towards the casing 200 to form an aperture therein.
  • the aperture is created through at least the front wall of the casing section 200' at an angle substantially perpendicular to the longitudinal axis of the outer casing 200.
  • a retention mechanism such as a pin 165 is then inserted through the casing 200' to ensure that any inner string of casing 205 is longitudinally fixed with respect to the outer string of casing 200.
  • the next step involves actuation of the band saw 120.
  • actuation of the band saw 120 is performed remotely via the control panel 125.
  • the blade 121 of the band saw 120 is actuated, and is advanced through the casing 200' at a point above the pin 165.
  • the retention pin 165 anchors the smaller diameter casing 205 within the larger diameter casing 200.
  • the severed portion of the casing section 200' is then lifted away, leaving an upper end of the lower portion of casing 200" remaining within the clamping assembly 130.
  • an elevator or other lifting device works with the slips to lift the casing 200' another predetermined distance upwards.
  • the slips 172 are then used to re-grasp the casing 200' for the operation to be repeated.
  • the clamp assembly 130 is deactivated, and the gate 135 is reopened so that the apparatus 100 can move away from the severed piece of casing 200'.
  • the pin 165 may be retained in the newly lifted section of casing 200' to be severed. A new pin 165 can then be inserted once a new aperture is formed within the casing 200'.
  • the apparatus 100 of the present invention provides a safe and efficient means for severing casing during a plug and abandonment operation.
  • the apparatus 100 is operated via a remotely located control panel 125.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Punching Or Piercing (AREA)
  • Perforating, Stamping-Out Or Severing By Means Other Than Cutting (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)

Claims (39)

  1. Dispositif (100) de séparation d'un tubage (200) au-dessus d'un puits de forage, le dispositif comprenant:
    un assemblage de serrage (130) construit et agencé de sorte à retenir le tubage par rapport au dispositif;
    un assemblage de forage (150) construit et agencé de sorte à former une ouverture à travers le tubage et à travers un quelconque train de tubes interne (205) emboîté dans le tubage, l'ouverture étant dimensionnée de sorte à recevoir un élément de retenue (165) pour ancrer le tubage sur le quelconque train de tubes emboîté; et
    un assemblage de coupe (120) construit et agencé de sorte à séparer le tubage et le quelconque autre train de tubes emboîté en formant une découpe travers le tubage;
    caractérisé en ce que l'assemblage de serrage, l'assemblage de forage et l'assemblage de coupe sont agencés suffisamment près les uns des autres pour que le dispositif puisse assurer les opérations de serrage, de forage et de coupe sans exiger un déplacement du tubage entre les opérations.
  2. Dispositif selon la revendication 1, dans lequel l'assemblage de serrage (130) comprend:
    au moins deux éléments de serrage (140) destinés à s'engager dans le tubage; et
    une porte (135) pouvant se déplacer sur une charnière (133) pour ouvrir et fermer sélectivement la porte, la porte comportant au moins un élément de serrage qui y est agencé.
  3. Dispositif selon la revendication 2, dans lequel chaque élément de serrage définit une paire de blocs de support inclinés.
  4. Dispositif selon les revendications 2 ou 3, dans lequel la porte (135) pour l'assemblage de serrage (130) peut être actionnée à distance.
  5. Dispositif selon les revendications 2, 3 ou 4, dans lequel l'assemblage de serrage (130) comprend en outre un capteur pour un des au moins deux éléments de serrage (140), pour détecter la pression exercée par l'élément de serrage contre le tubage (200) lorsque la porte (135) est fermée.
  6. Dispositif selon l'une quelconque des revendications précédentes, dans lequel l'assemblage de forage (150) comprend:
    au moins un trépan de forage (151) pour forer l'ouverture; et
    un moteur rotatif pour faire tourner le au moins un trépan de forage.
  7. Dispositif selon la revendication 6, comprenant en outre un dispositif de positionnement (156) pour faire avancer la position du trépan de forage (151) à travers le tubage (200') au cours de l'opération de forage, après le serrage du tubage par l'assemblage de serrage (130).
  8. Dispositif selon la revendication 7, dans lequel le dispositif de positionnement (156) du trépan de forage (151) de l'assemblage de forage (150) peut être actionné à distance.
  9. Dispositif selon les revendications 6, 7 ou 8, dans lequel l'assemblage de forage (150) comprend en outre:
    un capteur pour détecter la pression entre le au moins un trépan de forage (151) et le tubage engagé (200') au cours de la procédure de forage;
    un capteur pour détecter le déplacement par rotation du au moins un trépan de forage en tours par minute.
  10. Dispositif selon l'une quelconque des revendications précédentes, dans lequel l'assemblage de coupe (120) englobe une scie à ruban, comprenant:
    une lame (121) comportant plusieurs dents;
    au moins deux roues autour desquelles la lame est guidée; et
    un boîtier (122) pour les au moins deux roues, le boîtier comportant une première ouverture à travers laquelle la lame sort du boîtier et une deuxième ouverture à travers laquelle la lame rentre dans le boîtier.
  11. Dispositif selon la revendication 10, dans lequel la scie à ruban comprend en outre:
    une première paire d'éléments de rouleau (123) agencée au niveau de la première ouverture du boîtier (122) à travers laquelle la lame (2) est amenée; et
    une deuxième paire d'éléments de rouleau (123) agencée au niveau de la deuxième ouverture du boîtier, à travers laquelle la lame est reçue;
    les première et deuxième paires d'éléments de rouleau guidant la lame pour découper le tubage (200') à un angle pratiquement perpendiculaire à l'axe longitudinal du tubage.
  12. Dispositif selon les revendications 10 ou 11, comprenant en outre un dispositif de positionnement (126) pour faire avancer la position de la lame (121) à travers le tubage (200') au cours de l'opération de coupe, après le serrage du tubage par l'assemblage de serrage.
  13. Dispositif selon la revendication 12, dans lequel le dispositif de positionnement (126) de la lame (121) de la scie (120) peut être actionné à distance.
  14. Dispositif selon l'une quelconque des revendications 10 à 13, dans lequel l'angle du boîtier (122) de la scie à ruban (120) est décalé de l'angle auquel les dents de la lame (121) s'engagent dans le tubage (200') au cours de l'opération de coupe.
  15. Dispositif selon l'une quelconque des revendications 10 à 14, dans lequel le boîtier (122) de la scie à ruban (120) comprend un espacement agrandi entre les roues, l'espacement étant dimensionné de sorte à recevoir le tubage (200') lors de l'avance de la lame (121) de la scie à travers le tubage au cours d'une opération de coupe.
  16. Dispositif selon la revendication 1, dans lequel l'assemblage de serrage comprend:
    un cadre (134);
    au moins deux éléments de serrage (140) destinés à s'engager par frottement dans le tubage;
    une charnière (133) montée sur le cadre; et
    une porte (135) pouvant se déplacer sur la charnière pour ouvrir et fermer sélectivement l'assemblage de serrage, la porte comportant au moins un élément de serrage qui y est agencé;
    l'assemblage de forage comprenant:
    un trépan de forage (151) pour forer l'ouverture;
    un moteur rotatif pour faire tourner le trépan de forage; et
    un dispositif de positionnement (156) pour faire avancer la position du trépan de forage à travers le tubage au cours de l'opération de forage, après le serrage du tubage par le dispositif de serrage;
    la lame à ruban comprenant:
    une lame (121) comportant plusieurs dents;
    au moins deux roues autour desquelles la lame est guidée;
    un boîtier (122) pour les au moins deux roues, le boîtier comportant une première ouverture à travers laquelle la lame sort du boîtier et une deuxième ouverture à travers laquelle la lame rentre dans le boîtier;
    une première paire d'éléments de rouleau (123) agencée au niveau de la première ouverture du boîtier (122) à travers laquelle la lame (2) est amenée; et une deuxième paire d'éléments de rouleau (123) agencée au niveau de la deuxième ouverture du boîtier, à travers laquelle la lame est reçue; les première et deuxième paires d'éléments de rouleau guidant la lame pour découper le tubage (200') à un angle pratiquement perpendiculaire à l'axe longitudinal du tubage; et
    un dispositif de positionnement (126) pour faire avancer la position de la lame (121) à travers le tubage (200') au cours de l'opération de coupe, après le serrage du tubage par l'assemblage de serrage.
  17. Dispositif selon la revendication 16, dans lequel chaque élément de serrage (140) définit une paire de blocs de support inclinés.
  18. Dispositif selon les revendications 16 ou 17, dans lequel:
    l'angle du boîtier (122) de la scie à ruban (120) est décalé de l'angle auquel les dents de la lame (121) s'engagent dans le tubage (200') au cours de l'opération de coupe; et
    le boîtier (122) de la scie à ruban (120) comprend un espacement agrandi entre les roues, l'espacement étant dimensionné de sorte à recevoir le tubage (200') lors de l'avance de la lame (121) de la scie à travers le tubage au cours d'une opération de coupe.
  19. Dispositif selon les revendications 16, 17 ou 18, dans lequel:
    l'assemblage de serrage (130) comprend en outre un capteur sur l'un des au moins deux éléments de serrage (140) pour détecter la pression exercée par l'élément de serrage contre le tubage (200) lorsque la porte (135) est fermée;
    l'assemblage de forage (150) comprend en outre un capteur pour détecter la pression entre le au moins un trépan de forage (151) et le tubage engagé au cours de la procédure de forage; et un capteur pour détecter le déplacement par rotation du au moins un trépan de forage en tours par minute; et
    la scie à ruban comprend en outre un capteur pour détecter la pression entre la lame et le tubage engagé au cours de la procédure de coupe.
  20. Dispositif selon l'une quelconque des revendications 16 à 19, dans lequel:
    la porte (135) de l'assemblage de serrage (130) peut être actionnée à distance;
    le dispositif de positionnement (156) du trépan de forage (151) de l'assemblage de forage peut être actionné à distance; et
    le dispositif de positionnement (126) de la lame (121) de la scie (120) peut être actionné à distance.
  21. Dispositif selon l'une quelconque des revendications précédentes, comprenant en outre un bras télescopique (110) pour faire avancer sélectivement le dispositif (100) vers le tubage (200') et à l'écart de celui-ci, le dispositif étant agencé près d'une extrémité du bras.
  22. Dispositif selon la revendication 1, comprenant:
    un assemblage de séparation tubulaire (100);
    une barre de support (116); et
    une seule structure extensible en porte-à-faux (110) comportant une première extrémité et une deuxième extrémité, la structure extensible étant fixée sur la barre de support au niveau de la première extrémité et fixée à l'assemblage de séparation tubulaire au niveau de la deuxième extrémité.
  23. Dispositif selon la revendication 22, dans lequel la structure extensible définit un bras télescopique comportant un cylindre externe (110) et une section à télescopage d'extrémité (112).
  24. Dispositif selon la revendication 23, dans lequel le bras télescopique (110) peut pivoter autour d'un axe vertical.
  25. Dispositif selon les revendications 23 ou 24, dans lequel le bras télescopique (110) peut pivoter autour d'un axe horizontal.
  26. Dispositif selon les revendications 23, 24 ou 25, dans lequel le bras télescopique (110) comprend en outre une section à télescopage intermédiaire.
  27. Dispositif selon la revendication 26, dans lequel l'assemblage de séparation tubulaire est fixé de manière mobile sur la section à télescopage d'extrémité (112).
  28. Dispositif selon les revendications 26 ou 27, dans lequel:
    au moins une partie de la section à télescopage d'extrémité (112) est montée par glissement dans la section à télescopage intermédiaire; et
    au moins une partie de la section à télescopage intermédiaire est montée par glissement dans le cylindre externe (110).
  29. Dispositif selon l'une quelconque des revendications 23 à 28; comprenant en outre un élément de serrage pour fixer le cylindre externe (110) sur la barre de support (116).
  30. Dispositif selon la revendication 29, dans lequel le cylindre externe (110) peut être déplacé entre une première position et une deuxième position par rapport à la barre de support (116).
  31. Dispositif selon la revendication 30, comprenant en outre un moteur pouvant être actionné pour ajuster la position de la structure extensible (110) par rapport à la barre de support (116).
  32. Dispositif selon les revendications 30 ou 31, dans lequel l'assemblage de serrage est connecté de manière amovible sur la barre de support.
  33. Dispositif selon la revendication 1, comprenant:
    une base (114);
    une barre de support pratiquement verticale (116) au-dessus de la base;
    un élément de serrage fixé sur la barre de support;
    un seul bras télescopique en porte-à-faux (110) comportant une première extrémité et une deuxième extrémité, le bras télescopique étant fixé sur la barre de support au niveau de la première extrémité et fixé à l'assemblage de séparation au niveau de la deuxième extrémité.
  34. Dispositif selon la revendication 33, dans lequel l'élément de serrage est connecté de manière amovible sur la barre de support (116).
  35. Dispositif selon les revendications 33 ou 34, dans lequel la seule structure en porte-à-faux comprend un cylindre externe (110) et une section à télescopage d'extrémité (112), et au moins une section à télescopage intermédiaire, et dans lequel:
    au moins une partie de la section à télescopage d'extrémité est montée par glissement dans la section à télescopage intermédiaire; et
    au moins une partie de la section à télescopage intermédiaire est montée par glissement dans le cylindre externe (110).
  36. Procédé de séparation d'un tubage (200'), comprenant les étapes ci-dessous:
    formation d'une ouverture à travers le tubage et à travers un quelconque train de tubes interne (205) qui y est emboîté, par l'intermédiaire d'un assemblage de forage (150);
    ancrage du tubage et d'un quelconque train de tubes emboîté; et
    séparation du tubage par l'intermédiaire d'un assemblage de coupe (120), l'assemblage de coupe comprenant une lame (121) pour former une découpe;
    caractérisé en ce que l'assemblage de forage et l'assemblage de coupe sont suffisamment proches l'un de l'autre pour empêcher un déplacement axial du tubage entre les étapes de formation de l'ouverture et de séparation du tubage.
  37. Procédé de séparation d'un tubage selon la revendication 36, comprenant en outre l'étape de serrage du dispositif (100) sur le tubage (200') avant de forer l'ouverture à travers le tubage.
  38. Procédé de séparation d'un tubage selon les revendications 36 ou 37, comprenant en outre l'étape d'insertion d'une goupille (165) à travers l'ouverture pour fixer le quelconque train de tubes emboîté dans le tubage, l'assemblage de coupe (120) étant ensuite actionné pour former une découpe à travers le tubage au-dessus de la goupille, le tubage n'étant pas déplacé axialement à travers le dispositif entre l'étape d'insertion de la goupille et d'actionnement de l'assemblage de coupe.
  39. Procédé de séparation d'un tubage selon les revendications 36, 37 ou 38, dans lequel le dispositif de séparation du tubage (100) est agencé près d'une extrémité d'un bras télescopique (110) destiné à faire avancer sélectivement le dispositif vers le tubage et à le rétracter à l'écart de celui-ci.
EP02720112A 2001-03-20 2002-03-20 Procede et dispositif de separation de tiges faites d'elements tubulaires emboites Expired - Lifetime EP1370745B1 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US27743901P 2001-03-20 2001-03-20
US277439P 2001-03-20
PCT/GB2002/001339 WO2002075097A2 (fr) 2001-03-20 2002-03-20 Procédé et dispositif de séparation de tiges faites d'éléments tubulaires emboîtés

Publications (2)

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EP1370745A2 EP1370745A2 (fr) 2003-12-17
EP1370745B1 true EP1370745B1 (fr) 2006-05-24

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EP02720112A Expired - Lifetime EP1370745B1 (fr) 2001-03-20 2002-03-20 Procede et dispositif de separation de tiges faites d'elements tubulaires emboites

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EP (1) EP1370745B1 (fr)
AU (1) AU2002251182B2 (fr)
CA (1) CA2433362C (fr)
DE (1) DE60211667D1 (fr)
NO (1) NO331324B1 (fr)
WO (1) WO2002075097A2 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN111927369A (zh) * 2020-07-17 2020-11-13 华运隆腾机械制造有限公司 井口装置

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB201314323D0 (en) 2013-08-09 2013-09-25 Weatherford Uk Ltd Tubular stabbing guide
US10648255B2 (en) 2018-03-09 2020-05-12 Weatherford Technology Holdings, Llc Tubular stabbing guide for tong assembly
CA3036617A1 (fr) 2018-03-15 2019-09-15 Nabors Lux 2 Sarl Guide de tuyau
NO347597B1 (en) * 2021-12-17 2024-01-22 Archer Oiltools As A petrolium platform auxiliary rig and method of removing a well tubing from a petroleum well

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4181196A (en) * 1977-06-23 1980-01-01 Exxon Production Research Company Method and apparatus for recovery of subsea well equipment
US4557628A (en) * 1981-10-14 1985-12-10 Armco Inc. Method and apparatus for remotely cutting broken underwater guidelines
GB9325329D0 (en) * 1993-12-10 1994-02-16 Ocean Techn Services Ltd Offshore wellheads
NL1001807C2 (nl) * 1995-12-04 1997-06-06 Noordhoek Overseas Equipment B Werkwijze en inrichting voor het verwijderen van het bovenste gedeelte van een zich in de zeebodem bevindende constructie.
GB2313859B (en) * 1996-03-28 2000-07-12 Uwg Ltd Clearing sub-sea well risers

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN111927369A (zh) * 2020-07-17 2020-11-13 华运隆腾机械制造有限公司 井口装置
CN111927369B (zh) * 2020-07-17 2021-05-25 华运隆腾机械制造有限公司 井口装置

Also Published As

Publication number Publication date
NO331324B1 (no) 2011-11-28
NO20032934L (no) 2003-08-27
WO2002075097A2 (fr) 2002-09-26
NO20032934D0 (no) 2003-06-26
WO2002075097A3 (fr) 2003-02-06
EP1370745A2 (fr) 2003-12-17
AU2002251182B2 (en) 2007-08-16
DE60211667D1 (de) 2006-06-29
CA2433362A1 (fr) 2002-09-26
CA2433362C (fr) 2006-07-18

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