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
  • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
  • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
  • E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
  • E21B17/1021—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well with articulated arms or arcuate springs
  • E21B17/1028—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well with articulated arms or arcuate springs with arcuate springs only, e.g. baskets with outwardly bowed strips for cementing operations

Definitions

• the present disclosure generally relates to a centralizer having atmospheric chamber for expansion in response to hydrostatic pressure.
• US 4,523,640 discloses a well logging instrument including a body member supporting one or more arm members which may be biased outwardly against the sidewalls of the borehole.
• the arm members may be held in a closed position, adjacent the body member, during entry into a borehole by a heat sensitive retaining member.
• the heat sensitive retaining member will within a preselected temperature range release the arm member allowing the arm members to expand outwardly from the body member into contact with the sides of the borehole.
• US 5,097,905 discloses a centralizer for well casing including an externally threaded upper anchor fixed to the casing, an upper collar threaded to the upper anchor, a lower anchor fixed to the casing, a lower collar bearing against said lower anchor, and a plurality of relatively flexible metallic straps extending between the collars.
• the centralizer is assembled over a section of well casing as the casing is lowered into the well. When the casing reaches its final depth, it is rotated so that the anchors rotate with the casing, while the collars and the straps remain stationary, as the straps engage the wellbore.
• US 5,261 ,488 discloses, at Figures 18 and 18A and col. 7, line 40-col. 8, line 2, a centralizer restrained in a retracted position by a strap which is released by a piston operated by hydrostatic pressure.
• US 8,360,161 discloses a temperature activated actuator installed on a tubular to actuate an adjacent device may include one or more shape-memory alloy elements. The elements may be coupled between a first portion and a second portion of a device, or the elements may be coupled between the tubular and a portion of the device. The elements are activated by raising the temperature to a transition temperature to cause metallurgical phase transformation, causing the elements to shrink and displace at least a portion of the device.
• the actuator may be used, for example, to actuate a centralizer from a run-in mode to a deployed mode or, alternately, to actuate a packing member from a run-in mode to an isolating mode.
• a nickel-titanium alloy for example, may be used as the shape-memory alloy material from which the shape-memory element is made.
• US 9,580,976 discloses a centralizer assembly that allows for the assembly to be deployed in-situ.
• the centralizer assembly includes flexible members that can be extended into the well bore in situ by the initiation of a gas generating device.
• the centralizer assembly can support a large load carrying capability compared to a traditional bow spring with little or no installation drag. Additionally, larger displacements can be produced to centralize an extremely deviated casing.
• US 2015/0034336 discloses a centralizer having bow springs in a retracted position to facilitate passage through a restriction. After passing through the restriction, the bow springs may be expanded to support a casing. In one embodiment, the bow springs may be expanded using a movable sleeve.
• a centralizer for use in a wellbore includes: a body for disposing around a periphery of a casing or liner string, the body having a plurality of bow springs biased toward an expanded position; a mandrel for disposing around the periphery of the casing or liner string; a piston disposed around the mandrel and movable between a locked position and a release position; a plurality of dogs, each dog mounted to or formed integrally with the respective bow spring and captured by the piston in the locked position, thereby keeping the bow springs in a retracted position; an atmospheric chamber formed between the piston and the mandrel; and a fastener for releasably connecting the piston to the mandrel in the locked position.
• Figure 1 illustrates a casing or liner string equipped with a plurality of centralizers, each centralizer having an atmospheric chamber for expansion in response to hydrostatic pressure, according to one embodiment of the present disclosure.
• Figures 2A, 2B, and 3A illustrate a typical one of the centralizers in the retracted position.
• Figures 2C, 2D, and 3B illustrate the typical one of the centralizers in the expanded position.
• Figure 1 illustrates a casing or liner string 1 equipped with a plurality of centralizers 2a-e, each centralizer having an atmospheric chamber 8 ( Figure 3A) for expansion in response to hydrostatic pressure, according to one embodiment of the present disclosure.
• the centralizers 2a-e may each be mounted to the casing or liner string 1 along at least a portion thereof that will be cemented into a wellbore (not shown).
• the centralizers may be spaced along the portion of the casing or liner string 1 at regular intervals.
• Each centralizer 2a-e may be initially restrained in a retracted position (centralizers 2a-c) and may actuate to an expanded position (centralizers 2d,e) in response to being lowered past an actuation depth 3 in the wellbore.
• Each centralizer 2a-e may be set to actuate to the expanded position at the same actuation depth 3 or the centralizers may be set to different depths depending on their position along the casing or liner string 1. Having the centralizers 2a-e in the retracted position reduces frictional resistance when lowering the casing or liner string 1 into the wellbore and/or may safeguard against damage from the expanded centralizers scraping against sensitive components, such as seal bores in the wellhead.
• FIGs 2A, 2B, and 3A illustrate a typical one 2 of the centralizers 2a-e in the retracted position.
• the typical centralizer 2 may include a pair of collars 4p,w, a body 5, a plurality of dogs 6, a piston 7p, a mandrel 7m, an atmospheric chamber 8, a shearable fastener 9, and an anchor 10.
• the body 5 may have a pair of end rings 5p,w and a plurality of bow springs 5b extending therebetween.
• the bow springs 5 may be spaced around the body 5 at regular intervals (eight bow springs spaced at forty-five degree intervals shown).
• Bypass passages may be formed between the bow springs 5b to accommodate fluid flow through an annulus formed between the casing or liner string 1 and the wellbore.
• the bow springs 5b may each be identical and radially movable between an expanded position ( Figures 2C, 2D, and 3B) and the retracted position (shown).
• the bow springs 5b may have a parabolic shape in the expanded position.
• the body 5 may longitudinally extend when moving from the expanded position to the retracted position and longitudinally contract when moving from the retracted position to the expanded position.
• the bow springs 5b may be naturally biased toward the expanded position and an expanded diameter of the centralizer 2 may correspond to a diameter of the wellbore. Engagement of the bow springs 5b with a wall of the wellbore may move the casing or liner string 1 toward a central position within the wellbore to ensure that a uniform cement sheath is formed around the casing or liner string 1 during the cementing operation.
• the body 5 may be formed from a single sheet of spring steel by cutting out slots to form strips which will become the bow springs 5b.
• the body 5 may be formed into a tubular shape by rolling the cut sheet and welding seams of the end rings 5p,w together.
• the bow springs 5b may have the natural bias toward the expanded position by being held therein during heat treatment of the body 5.
• each collar 4p,w may be inserted into the respective end rings 5p,w.
• Each collar 4p,w may be formed to be a tight fit within the end rings 5p,w.
• Each collar 4p,w may then be spot-welded to the respective end rings 5p,w.
• a lip of each end ring 5p,w extending past the respective collar 4p,w may be split into a multitude of tabs (before or after insertion of the collars) and the tabs may be bent over the respective collar, thereby mounting the collars to the body 5 (in addition to the spot welds).
• the anchor 10 may include a locking ring 10r and a plurality of set screws 10s.
• the locking ring 10r may have a plurality of threaded sockets formed through a wall thereof and spaced therearound. The set screws 10s may be driven into the threaded sockets and into engagement with a periphery of the casing or liner string 1 , thereby mounting the locking ring 10r to the casing or liner string.
• the locking ring 10r may be located between the collars 4p,w by insertion through one of the slots between the bow springs 5b before the centralizer 2 is slid over the periphery of the casing of liner string 1.
• Setting of the anchor 10 may trap the centralizer 2 into place along the casing or liner string 1 while allowing limited longitudinal movement of the body 5 relative thereto to accommodate movement between the positions.
• One of the dogs 6 may be mounted to each bow spring 5b at a mid portion thereof.
• the mid portion of each bow spring 5b may have a groove formed therein for receiving the respective dog 6 and each dog may be mounted to the respective bow spring, such as by welding.
• the mandrel 7m may be disposed around the periphery of the casing or liner sting 1 and may be located between the anchor 10 and the upper collar 4p. The mandrel 7m may abut the locking ring 10r when the centralizer 2 is in the retracted position.
• the mandrel 7m may have a reduced outer diameter upper sleeve, an enlarged outer diameter lower foot, and a shoulder connecting the sleeve and the foot.
• the foot of the mandrel 7m may have an upper groove formed in a periphery thereof and a lower groove formed in the periphery thereof.
• the upper groove of the mandrel 7m may carry an elastomeric seal 11 , such as an o-ring, and the lower groove may carry the shearable fastener 9, such as a shear ring.
• each dog 6 may be formed integrally with the respective bow spring 5b.
• each dog 6 may be mounted to the respective bow spring 5b by having wings wrapped around the respective bow spring instead of by welding.
• the piston 7p may be disposed around the periphery of the mandrel 7m and may be located between the anchor 10 and the upper collar 4p.
• the piston 7p may have a reduced inner diameter upper head, an enlarged inner diameter lower sleeve, and a shoulder connecting the sleeve and the head.
• the head of the piston 7p may have a groove formed in an inner surface thereof.
• the groove of the piston 7p may carry an elastomeric seal 11 , such as an o-ring.
• the head diameter of the piston 7p may correspond to the sleeve diameter of the mandrel 7m and the sleeve diameter of the piston may correspond to the foot diameter of the mandrel.
• the piston 7p may be longitudinally moveable relative to the mandrel 7m between an upper locked position (shown) and a lower release position (figures 2D and 3B).
• the head of the piston 7p may trap the dogs 6 therein in the locked position, thereby restraining the bow springs 5b in the retracted position against their natural bias toward the expanded position.
• an inner surface of the head of the piston may have a conical portion for receiving the dogs and an outer surface of each dog may have an inclined portion for engagement with the conical portion of the head.
• the inner surface of the head of the piston 7p may have a straight portion for receiving the dogs 6 and the outer surface of each dog may have a straight portion for engagement with the straight portion of the head or the inner surface of the head of the piston may be partially straight and partially conical and the outer surface of each dog may be partially straight and partially inclined.
• the atmospheric chamber 8 may be formed radially between the sleeves of the mandrel 7m and the piston 7p and longitudinally between the shoulders of the mandrel and the piston. Interfaces between the piston 7p and the mandrel 7m may be sealed by engagement of the seal 11 of the mandrel 7m with the sleeve of the piston 7p and by engagement of the seal of the piston with the sleeve of the mandrel.
• the head of the piston 7p may be exposed to hydrostatic pressure during lowering of the centralizer 2 into the wellbore.
• the piston may be in the release position while the bow springs 5b are retracted using a strap.
• the piston 7m may then be moved to the locked position and the shearable fastener 9 then inserted into the lower groove of the mandrel 7m.
• the shearable fastener 9 may be a snap ring.
• the strap may then be released from the bow springs 5b.
• An outer diameter of the shearable fastener 9 may correspond to an outer diameter of the piston 7p such that the shearable fastener releasably connects the piston to the mandrel 7m, thereby preventing movement of the piston from the locked position to the release position.
• FIGs 2C, 2D, and 3B illustrate the typical one 2 of the centralizers 2a-e in the expanded position.
• the force exerted on the piston 7p by the hydrostatic pressure acting on the head thereof reaches a threshold force to fracture the shearable fastener 9, thereby allowing the piston 7p to move downward from the locked position to the release position and releasing the dogs 6 from captivity.
• the natural bias of the bow springs 5b may move the centralizer 2 from the retracted position toward the expanded position (or at least until stopped by engagement of the bow springs with the wall of the wellbore).
• the casing or liner string 1 may be lowered to a deployment depth with all of the centralizers 2a-e still in the retracted position and then annulus or hydrostatic pressure in the wellbore may be increased to actuate the piston 7p.
• the annulus pressure may be increased by closing a blowout preventer and circulating fluid down the casing or liner string 1 and through a choke line of the wellhead.
• the hydrostatic pressure may also be increased by lowering the casing or liner string with a less dense fluid in the wellbore and then replacing the less dense fluid with a more dense fluid after the casing or liner string has been lowered to the deployment depth.

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

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Citations (6)

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• 2019
  • 2019-07-24 EA EA202190187A patent/EA202190187A1/ru unknown
  • 2019-07-24 EP EP19773521.0A patent/EP3833846A1/en not_active Withdrawn
  • 2019-07-24 CN CN201980051276.3A patent/CN112534115A/zh active Pending
  • 2019-07-24 WO PCT/IB2019/056329 patent/WO2020031010A1/en unknown
  • 2019-07-24 US US17/259,643 patent/US20210270092A1/en not_active Abandoned

Patent Citations (6)

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