JPS585355B2 - Idoyo Mitsupei Kumitatetai - Google Patents

Description

DETAILED DESCRIPTION OF THE INVENTION The present invention relates to a sealed connection structure between pipes used in oil drilling, etc., and in particular, the wells (second cylindrical member) formed at the tips of the pipes are provided with vertical grooves. The present invention relates to a sealing assembly including a locking assembly used for removably sealingly connecting a case (pipe) with a casing banger.

Fluted bangers are commonly used to support casings inside wells.

The annulus (seam) between the outer circumference of this fluted banger and the inner circumference of the wells must be sealed.

Also, it is an old method to use a sealing element, typically a resilient clamping type, which is locked inside the ring and tightened in a sealed state.

However, such sealing assemblies generally have the disadvantage that they must be remotely engaged and energized by rotating a screw, which is difficult and difficult to install when drilling offshore oil fields from a drilling vessel. It had the disadvantage that the counterclockwise rotation used for sushi was the same as the rotation of a drill bit during drilling.

The present invention relates to an improved fastening assembly for securing a sealing assembly or other well member to a cylindrical well member with a locking, notch.

The present invention also provides a closed assembly in which (1) all operations are done by pushing, pulling or clockwise rotation;
) Stop all operations by rotating counterclockwise, and (3)
(4) each part has a limited vertical dimension to prevent parts of the assembly from becoming dislodged during installation and removal; connected by a motion connection from the direction (5)
wells or casings, locked on top of bangers;
(6) the pressure applied to the installation tool during the pressure test is designed to provide an actual pressure test on the seal without loading the seal; and (7) the actuation of the elastic seal is designed to impart rotation. It also relates to various improvements, such as those made through a non-threaded engagement (J-groove).

One object of the present invention is to provide a locking assembly for use in wells that includes a first member that can be locked into wells with a locking notch.

That is, a locking dog capable of engaging with a notch of the well and a locking sleeve capable of fitting inside the dog are disposed on the first member.

A wedge-like locking surface is formed between the sleeves and the dogs, and only longitudinal movement of the sleeves locks and unlocks the dogs from the notches.

The first member and the sleeve are arranged such that the tightening of the dog allows longitudinal movement for actuation and release movements, prevents the first member from dislodging from the sleeve, and further allows for limited longitudinal movement relative to each other. It is arranged in a telescopic manner (putting a puppy) through a structure of free movement (play).

Another object of the invention is to provide a sealing assembly that provides a seal between a well and a banger.

This sealing assembly is the first part of the locking assembly.
and a second member (
A pressing member) and an elastic sealing means (sealing ring) that is pressed by the suppressing member to seal between the well and the sealing assembly.

This first member is formed with a non-threaded engagement portion (5-shaped groove group) through which rotation is transmitted.

This second member is threadedly connected to the first member with a left-handed connection.

Also, right-handed rotation of the first member compresses the resilient sealing means (without requiring left-handed rotation of the drill pipe during drilling).

A further object of the present invention is to set the sealing means such that the clamping means rotates the first member such that the clamping mechanism retains the device in place while the clamping mechanism allows the device and closure assembly to perform the desired function. The purpose is to provide a motion connection from a limited vertical direction that can be given.

One of the seal assembly members includes a shoulder that contacts the bottom of the dog to provide a stop for applying a pushing force against the resilient seal.

It is another feature of the invention that the closure assembly is removed from the well by pulling the sleeve lengthwise to release the dog from the notch.

Yet another object of the invention is to provide a sealing assembly including a third member.

Either one of the first and second members has a shoulder adjacent to the bottom of the locking dog, and a left-handed threaded connection is provided between the first and second members, whereby Right-handed rotation of the first member moves either member downwardly to set a resilient seal.

A limited longitudinal free movement connection is provided between the third member and one of the first and second members to allow rotation but prevent the third member from moving apart.

Furthermore, a device is provided between the cylinder 3 member and the second member to allow only relative longitudinal movement.

Yet another object of the present invention is to provide a third member formed with a downwardly facing shoulder on which the banger rests and an upwardly facing shoulder on which the installation test tool rests.

This applies a downward force on the banger that would be applied to the installed test tool and avoids loading the resilient seal during pressure testing.

It is further an object of the invention that a second resilient seal is attached to the third member for sealing engagement with the casing and banger.

It is a further object of the present invention to provide a top surface of the casing, banger so that if for some reason the casing, banger is not set in the wellbore where it should be, the casing can still be completely sealed. It is provided with a sealing assembly that can be locked.

Embodiments of the invention will now be described with reference to the accompanying drawings, and in particular to FIG.

A conventional well 10 is installed in a wellbore, and a drill bit (not shown) is lowered into the well 10 to make a hole for the casing (pipe).

After the holes are drilled, the fluted casing 12 with the banger 14 is inserted into the driving tool 1 at the tip of the casing 18.
6 and is lowered downward and supported by wells 10.

The casing 12 is usually formed by pouring cement between the casing 18 and the casing 12 using a pump.
The casing 12 between the outside of 2 and the inside of the well 10
The space from the bottom to the top is filled with cement.

After the cement hardens, the driver 16 is removed from the banger 14 by rotating the casing 18 to the right.

4, 5 and 6, between the well 10 and the case 12 there is provided an improved sealing assembly 20 of the present invention that includes a locking assembly.

The sealing assembly 20 includes a convex member 80 disposed on the banger 14 and having a generally convex cross-section and having a sealing ring 72 on the outer periphery.
, a pressing member 70 that presses this sealing ring 72, and a first member 40 that is rotatably screwed into this pressing member.

A locking assembly, on the other hand, is used to lock the first member 40 to the second tubular wall member 10.

The preferred type of sealing assembly 20 is a notch 22 formed in the inner circumference of the wells 10 or the outer circumference of the banger 14 and is used to seal the annulus between the wells 10 and the banger 14.

This sealing assembly 20 is installed in a banger 1 in a well 10 by means of an installation test tool 24 that can be attached to a drill pipe 25.
4 will be lowered.

The installation test tool 24 includes a first portion 26 and a second portion 28, as shown in FIGS. 4 and 11.

A sleeve 50 is set (suppressed) in this first portion 26.
A downward facing shoulder 46 is formed.

Second portion 28 is also formed with a plurality of lugs 30 which are inserted into non-threaded engagement means, such as J-grooves 32, in first member 40.

In this installation test tool 24, an annular groove 36 is formed on the inner peripheral surface of the first portion 26, and an annular groove 34 wider than the groove 36 is formed on the outer peripheral surface of the second portion 28. 34.3
A ring 38 is inserted between the first and second portions 26 and 28 to connect the first portion 26 and the second portion 28 for limited free movement in the vertical direction.

Also number 1. Second portions 26 and 28 are formed with interlocking locking wedges 42 and grooves 44.

The installation test tool 24 is therefore constructed to drive the sealing assembly 20 by a longitudinal pushing motion and clockwise rotation, and thus can be locked or sealed at a remote location. , the left hand of the even more harmful drill pipe 25 (
(counterclockwise) rotation is avoided.

FIG. 4 shows the sealing assembly 20 in the installed position, just prior to locking.

The sealing assembly 20 includes an annular spring dog 48 that aligns and engages the locking notch 22 when secured onto the banger 14.

A vertically movable sleeve 50 that can move forward or backward is disposed at the rear of the dog 48.
0 has a downwardly facing shoulder 52 that can engage the extraction tool 110, an upwardly facing shoulder 54 that can engage the shoulder 46 of the installation test tool 24, and a rear (wedge face) of the dog 48. A locking surface, such as a wedge surface 56, is formed.

Thus, when the sleeve 50 is pushed downwardly by the installation test tool 24, the sleeve 50 slips behind the dog 48, thereby securing the dog 48 in the notch 22.

Note that FIG. 3 shows a sleeve without the shoulder 52 for removal.

In this case the sleeve is moved upwards by means such as a bar gripping the inner circumference.

A first member (rotating member) 40 is arranged to support the sleeve 50 and dog 48.

The sleeve 5 is rotated by the rotating member 40 shearbins 58.
Temporarily fixed at 0.

This shear pin 58 is cut when locked.

Further, the rotating member 40 is connected to the sleeve 50 with play.

i.e. this play (limited longitudinal lost motion connection)
is an annular groove 60 formed on the outer periphery of the rotating member 40;
It consists of an annular groove 62 formed on the inner periphery of the sleeve 50 and narrower in width than the groove 60, and a ring 64 inserted into these grooves 60, 62.

This configuration allows the sleeve 50 to move to the locked position, the rotating member 40 to rotate when locked, and further to allow the rotating member 40 and sleeve 50 to be taken out without separating when unlocked.

That is, the sleeve 50 can be pulled lengthwise to allow the closure assembly 20 to be removed.

Additionally, the first member 40 is inserted relative to the sleeve 50 for both longitudinal and rotational movement. The sealing assembly 20 also includes a second member (pushing member) 70 that allows for both longitudinal and rotational movement. A left-handed threaded connection 66 is formed between member 40 and second member 70 .

The first member 40 includes an abutment shoulder 68 adjacent the bottom of the dog 48 to prevent upward movement of the rotating member 40 when the dog 48 is positioned in the groove 22. .

That is, the clockwise rotation of the rotating member 40 causes the elastic sealing body 1 to rotate.
2 tightens against the well head 10.
move downward.

The member 80 of option 3 is provided with a suitable device 74 for preventing rotation, such as a pin 74, when the pin 14 is biased between the grooves of the banger 14 by the spring 16, causing the first member 40 to rotate. The second member 70 is moved downward without rotation.

In order to prevent this pressing member 10 from rotating, a third member (
A pin 78 is fixed to the sealing member) 80, and this pin 18
is slidably inserted into a hole 82 formed in the pressing member 70.

Further, the turning member 40 is attached to the sealing member 8 by a shear pin 84.
0, and the shear pin 84 is cut when the rotating member 40 rotates.

Such a rotating member 40 and a third member (sealing member) 80
A connection structure with play is also formed between the two.

This play (limited lost motion connection) is comprised of a groove 86 in the sealing member 80, a groove 88 in the rotating member 40, and a ring 90.

Further, the sealing member 80 has a metal plate on the surface that contacts the banger 14.
One or more elastic seals 94 or 96 are inserted to form the metal seal 92 and engage the banger 14 to further complete the seal.

As best shown in FIGS. 5 and 6, the sealing assembly 20 is attached to a test tool 2 connected to a drill pipe 25.
4 and descends inside the casing to form wells 10.
placed on top of the inner banger 14.

Next, when the installation test tool 24 is rotated slightly clockwise and pushed, the sleeve 50 is first pushed, cutting the shear pin 58 and forcing the sleeve 50 to slip behind the dog 4B.

This causes the dogs 48 to expand and engage the notches 24, securing the seal assembly 20 to the well 10.

At the same time, a clockwise rotation is applied to the installation test tool 24.

This rotational force is transmitted from the first portion 26 to the second portion 28 via the stop wedge 42 and the groove 44, and further transmitted to the rotating member 40 via the stop wedge 42 and the J-shaped groove 32. .

In this case, when the lug 42 engages the J-groove 32, the lug group 30 is aligned with the portion of the J-groove 32 where the installation test tool 24 is removed from the seal assembly 20.

During this fixing, the spring loaded pin 74 may not be inserted between the longitudinal grooves of the banger 14 as shown in FIG. 4.

In this case, the sealing member 80 is rotated by the shear pin 84 as the rotating member 40 rotates, causing the spring loaded pin 14 to slide off the top of the longitudinal grooves of the banger 14 and be inserted between the longitudinal grooves.

This secures the sealing member 80 to the banger 14 in a non-rotatable manner.

When the rotary member 40 rotates in this manner, the pin 84 is cut, and the second member 10 is screwed downward and the elastic seal 12 is removed.
As shown in Figure 14, wells 10 and bangers 1 are compressed.
40, or the ring between the wells 10 and the third member 80 as shown in FIG.

The sealing member 80 has its lower end set over the top of the banger 14 so that its upper shoulder 100 can contact the test tool 24 .

Therefore, the test tool does not load the sealing body 72 more than necessary even if pressure is applied between the well 10 and the drill pipe 25 during the test and the test tool is strongly pushed.

In order to test the sealing effectiveness of this seal, an explosion prevention device (safety valve, not shown) is installed to block the drill pipe 25 as shown in FIG. (between the tubes connected above the wells 10 and the drill pipe 25), into the annulus between the wells 10 and the pipes 25, and onto the top of the sealing assembly 20.

The installation test tool 24 also includes a closure 102 that seals the casing 12.

If this pressure is applied and there is no change, the sealing body 12
is good.

If this pressure decreases and there is no pressure return (pressure change in the drill pipe) via the drill pipe 25, then
The seal 12 is then leaking.

If pressure fluctuations occur inside the drill pipe 25, then either the seal 29 between the tool parts 26 and 28, or the seal 102 is leaking.

If the seal assembly 20 is overgrown, the tool 24 is pulled out of the well Q.

9 and 10, the bowling protection device 104 shown in FIGS. 5 and 6 is inserted into the well 10 before the drilling operation (bowling) after the test. is inserted with the same test tool 24.

The protector 104 is lowered until it is set on top of the closure assembly 200.

The tool 24 is then rotated to the right with a predetermined amount of torque resistance until the protector 104 is locked in place.

The locking mechanism is a pin 106 which is loaded and pushed outwardly by a spring 108, as best shown in FIG.
and into the J-slot 32 to lock in place.

When this protector 104 is in place, the test tool 24
Since it is detached from the mold slot attachment device, it is picked up and taken out.

The well is now ready for continued drilling.

The drill bit is moved through this protection device 104 into the interior of the casing 12 and into the hole that can be drilled to the desired depth.

When removing the bit from the hole, the protector 104 must be removed.

The drill in this case, the extraction tool 110 attached to the pipe 25, is best shown in FIGS. 7 and 8.
Simply place it on top of the protector 104 and pull it off the well jarring pin 106 to remove it.

As shown in FIGS. 1 and 3, the second fluted banger 114 and closure assembly 120 may be installed in a manner similar to that previously described with respect to the fluted banger 14 and closure assembly 20. I can do it.

When the sealing assembly 20 needs to be removed from the well head, the removal tool 1 is used, as best shown in FIGS. 1 and 8.
10 is connected to a drill and pipe 25.

The extraction tool 110 also includes a resilient locking ring 112 having an upwardly facing engagement shoulder 114.

When the extraction tool 110 is placed on top of the closure assembly 20,
The resilient ring 112 moves inwardly over the top shoulder 54 of the sleeve 50 until the engagement shoulder 114 moves downwardly and outwardly into engagement with the downward facing shoulder 52.

The closure assembly 20 is ejected by means of a vertically upward pulling force.

The upward pulling force exerted by the extraction tool 110 first pulls the sleeve 50 upward, causing the dog 48 to lock, elastically retreat from the notch 22, and come off.
Further, the ring 38 contacts the upper end of the slot 36 in the rotating member 40 to move the limited longitudinal lost motion connection upwardly, moving the rotating member 40 upwardly and in turn also the second member 70. By moving it upward, the sealing pressure on the elastic sealing body 72 is relieved, making removal easier.

The third member 80 is also moved upwardly through the ring 90 in the limited lost motion connection between the third member 80 and the first member 40 .

Therefore. If the sealing assembly 20 is accidentally retracted during removal,
In addition, the sleeve 50 can be easily moved by simply releasing the lock, retracting the elastic sealing body 71, and pulling up the sleeve 50.

Referring to the seal assembly 120 shown in FIG. 3, the shoulder 52 shown in the seal assembly 20 is omitted and the sleeve is removed by grasping its inner diameter with a suitable tool such as a rod. It can be taken out.

Furthermore, the dog 150 is an outwardly overloaded spring and the cooperating locking plane 15 on the sleeve.
2 need only move behind the dog 150 to lock the dog 150 in place.

The sealing assembly 120 eliminates the wedge surface between the sleeve and the dog.

However, if desired, a spring-loaded shear pin 1
54, when placed after dog 150, can be moved by the sleeve to engage a recess 156 in the first member to releasably hold the sleeve in a locked position.

Other variants are best shown in Figures 12.13 and 14, in which the same parts as in Figures 1 to 11 are labeled with the suffix "a", respectively.

They are designated by the same numbers with ``b'' and ``C'' etc.

Referring to FIG. 12, the notch 22a is located at the outer periphery of the fluted banger 14a instead of within the wellhead 10a.

If for some reason banger 14a becomes well head 10
Locking, even if it is not fixed precisely in a.
Since dog 48a is aligned with notch 22a, a seal is created.

That is, in this embodiment, the sleeve 50a is moved rearwardly and downwardly (outwardly) of the dog 48a, and the sealing assembly 2
0a is locked.

Also, when a clockwise rotation is applied to the first member 40a, the first member 40a moves downwardly to compress the resilient seal 72a since the second member 70a is adjacent the bottom of the dog 48a. I am made to do so.

A limited longitudinal lost motion connection including a ring 90a is between the third member 80a and the first member 40a and a two-way connection between the second member 70a and the third member 80a. A spline connection 1 that allows two members relative longitudinal movement with respect to each other but prevents rotational movement between them.
22 is formed.

In the embodiment shown in FIG. 13, the notch 2 is
2b is formed on the outer periphery of the longitudinally grooved banger 14b,
It differs from the embodiment of FIG. 12 in that first member 40b includes an abutment below dog 48b.

Sleeve 50b is moved vertically downward to lock behind locking 48b, after which a clockwise rotational force is applied to rotating member 40bK to move second member 70b downwardly and set seal 72b.

In yet another modification shown in FIG. 14, a notch 22c is provided around the inside of the head 10c.

Similarly, the elastic sealing body 72c, the wells 10c and the banger 1
4c to completely seal the ring between the second member 4
It includes a low portion 124 of 0c.

The lower portion 124 acts as a third member in the implementation to prevent rotation of the seal 72c and further includes a head 128 (path shown) extending into a counterbore 130 (path shown) at the end of the portion 124. ) is connected to the second member 70c by a limited longitudinal lost motion connection by a bolt 126 with a bolt 126 having a 126. This is followed by locking, which is moved downwardly behind dog 48c, and sleeve 50c.

A clockwise rotation is applied to the first member 40c, which in turn compresses the second member 7 so as to compress the resilient seal 22c against the lower member portion 124 as soon as the rotation is applied.
Move 0c downward.

Also, the sealing member 20c can only be moved by locking and pulling vertically upwardly onto the sleeve 50c.

[Brief explanation of the drawing]

Figure 1 is a cross-sectional view of the well showing the two casings suspended inside the well, each casing, and the sealing assembly mounted on the banger; Figure 2 is shown moving with the operating equipment; A plan view of the well location showing the fluted casing and banger. FIG. 3 is a partially enlarged chamber cross-sectional view of the two casings in the wellhead shown in FIG. 1, the two sealing assemblies locked in position with respect to the banger; and FIG. 4 is in position between the wellhead and the banger. Figure 5 is a partially enlarged chamber cross-sectional view of the assembly sealed in place and tested with a test tool; Location view of the sealing assembly being placed and tested, 1st
The figure is a sectional view showing the sealed assembly unlocked by pulling the sleeve with the extraction tool, Figure 8 is an enlarged partial elevational view of the sealed assembly with the lock and seal released, and Figure 9 is the sealed assembly. FIG. 10 is an enlarged partial cross-sectional view of the protector locked into the sealing assembly shown in FIG. 9; FIG. 11 is a view showing the installation test tool and 12 is an enlarged partial sectional view of a variant of the sealing assembly of the invention; FIG. 13 is a further variant of the sealing assembly of the invention in the locked and set position; FIG. FIG. 14 is an enlarged partial chamber sectional view of another variation of the sealing assembly of the present invention in the locked and set position. 10...Wells, 14...Banger,
20... Sealed assembly, 22 (22a)...
...locking, notch, 40...first member, 48...dog, 50...sleeve, 10...second member, 80... ...Third
parts.

Claims (1)

[Claims] 1. A dog that can be locked into a locking notch formed in a well or casing banger. a locking sleeve disposed longitudinally movable behind and away from the dog for locking and releasing the dog from the notch, and between the sleeve and the dog; a rotating member having a locking surface formed therein; a threadless retaining portion disposed in the sleeve and to which rotation is transmitted; and a rotating member configured to be freely rotatable between the sleeve and the rotating member. a second member (suppression member) that is threadedly engaged with the rotary member via a threaded connection; and a sealing body capable of sealing between the rotary member and the casing banger, one of the rotary member and the second member has a shoulder that can abut against the bottom of the dog, and the other has a shoulder portion that can abut against the bottom of the dog. A sealing assembly for a well, characterized in that a sealing effect is obtained by pressing the sealing body by rotation in a direction.