WO2019239085A1

WO2019239085A1 - Downhole apparatus and method

Info

Publication number: WO2019239085A1
Application number: PCT/GB2018/051626
Authority: WO
Inventors: Michael RONSON; Muhammad Ahmed; Eric MAIR
Original assignee: Weatherford UK Ltd; Weatherford Technology Holdings LLC
Current assignee: Weatherford UK Ltd; Weatherford Technology Holdings LLC
Priority date: 2018-06-13
Filing date: 2018-06-13
Publication date: 2019-12-19
Anticipated expiration: 2020-12-13
Also published as: NO20201365A1; SA520420765B1

Abstract

A downhole apparatus (10) comprises a landing arrangement (12) comprising a collet (18) and an actuation arrangement (14) comprising an actuation piston (22). The actuation arrangement (14) is operable to reconfigure the downhole apparatus (10) from the first configuration to a second configuration in which the landing arrangement (12) defines a radially retracted position, permitting the apparatus (10) to be run through a seat (S).

Description

DOWNHOLE APPARATUS AND METHOD

FIELD

A downhole apparatus and method.

BACKGROUND

In the oil and gas industry, in order to access hydrocarbons from a formation one or more borehole is drilled from surface, the borehole then being lined

(“completed”) with sections of bore-lining tubing known as casing which is cemented in place. In some instances, the lowermost section of the completion, known as the liner section or liner completion, is suspended from the casing above it rather than being tied back to surface.

It will be recognised that the completion of a borehole involves a significant number of operations.

For example, one such operation known as an inflow test involves the temporary and controlled under-balancing of the well in order to identify any integrity issues in the connections between the bore-lining tubing sections, such as between the casing and liner sections of the completion, the inflow test being important both for the operation efficiency of the completion and to ensure safe operation during the production phase.

Another common operation is a wellbore cleaning operation, such as a milling operation to remove debris and restore the borehole to the specified drift diameter.

While completion tools and equipment are becoming ever more sophisticated, there are a number of drawbacks with conventional systems. For example, each operation requires tools and equipment to be run into the wellbore and then retrieved to surface before the next operation can be carried out, increasing time and cost for the operator.

SUMMARY

According to a first aspect, there is provided a downhole apparatus comprising: a landing arrangement;

an actuation arrangement operatively associated with the landing arrangement, wherein the actuation arrangement is configured to reconfigure the apparatus from a first configuration in which the landing arrangement defines a radially extended position for supporting the apparatus on a seat and a second configuration in which the landing arrangement defines a radially retracted configuration, the landing arrangement in the radially retracted configuration permitting the apparatus to pass through the seat.

The apparatus may be coupled to, or form part of, a downhole assembly, such as a downhole work string, for use in performing one or more downhole operations in a cased borehole. In use, the apparatus may be run into the borehole, the apparatus during run in defining the first configuration in which the landing arrangement is arranged in the radially extended position arranged to land on the seat. The seat may, for example, be formed by the top of the liner (known as the Top of Liner or“TOL”). The actuation arrangement is operable to reconfigure the downhole apparatus from the first configuration to the second configuration in which the landing arrangement defines the radially retracted position, permitting the apparatus to be run through the seat, and permitting additional operations to be carried out. Beneficially, embodiments of the apparatus permit multiple downhole operations to be carried out in a single trip. By way of example, embodiments of the apparatus permit an inflow test to be performed and subsequent wellbore cleaning, drilling out, reaming and/or milling operations to be carried out in a single trip, providing significant time savings for the operator, and with consequential and substantial cost savings. Embodiments of the apparatus may also reduce the impact on operations which may otherwise be caused by damage at the time of drill out.

In the second configuration of the apparatus, the landing arrangement may define a smaller diameter than in the first configuration of the apparatus.

The landing arrangement may comprise a collet.

The collet may comprise a body.

The collet may comprise a plurality of collet fingers.

In the first configuration, the collet fingers may be radially extended.

In the second configuration, the collet fingers may be radially retracted.

The collet may be biased towards the second, radially retracted, position. The collet may be treated so that the collet is biased towards the second, radially retracted, position.

The collet may be heat treated so that the collet is biased towards the second, radially retracted, position.

The apparatus may comprise a mandrel.

The mandrel may support the landing arrangement in its radially extended position when the apparatus is in the first configuration.

The mandrel may support the landing arrangement in its radially retracted position when the apparatus is in the second configuration.

The landing arrangement may be configured for axially movement relative to the mandrel.

The landing arrangement may be axially movable relative to the mandrel to reconfigure the apparatus from the first configuration to the second configuration.

In use, axial movement of the landing arrangement relative to the mandrel moves the landing arrangement to an axial position in which the mandrel no longer maintains the landing arrangement in its first, radially extended, position, this de supporting of the landing arrangement permitting the landing arrangement to move to its second, radially retracted or smaller diameter, configuration.

The landing arrangement may be releasably coupled to the mandrel.

The landing arrangement may comprise a lock arrangement.

The lock arrangement may be configured to releasably lock the landing arrangement to the mandrel.

The lock arrangement may comprise one or more lock member.

The lock member may comprise a shearable member, such as a shear pin, shear screw, shear disk or the like.

The mandrel may comprise a body. An outer diameter of the body may define a drift diameter of the apparatus and/or downhole assembly.

The mandrel may be tubular in construction.

The mandrel may comprise an axial flow passage.

The axial flow passage may comprise an axial throughbore.

The mandrel may comprise a lateral flow passage.

The lateral flow passage may comprise one or more flow port.

The lateral flow passage may comprise a single port.

Alternatively, the lateral flow passage may comprise a plurality of ports. In embodiments where the lateral flow passage comprises a plurality of ports, two or more of the ports may be arranged circumferentially.

The mandrel may comprise a stepped outer surface.

The mandrel may comprise a first recess portion. The first recess portion may be annular.

The mandrel may comprise a second recess portion. The second recess portion may be annular.

The second recess portion may be configured to accommodate the landing arrangement when the apparatus is in the second configuration.

As described above, the actuation arrangement is operatively associated with the landing arrangement and is configured to reconfigure the apparatus from the first configuration in which the landing arrangement defines an extended position for supporting the apparatus on the seat and a second configuration in which the landing arrangement defines a radially retracted configuration, permitting passage of the apparatus past the seat.

The actuation arrangement may be pressure actuable.

The actuation arrangement may be operable in response to an applied fluid pressure force.

The actuation arrangement may be operable in response to the applied fluid pressure force exceeding a selected force threshold.

The actuation arrangement may comprise a piston.

The piston may be integrally formed with the landing arrangement.

Alternatively, the piston may comprise a separate component to the landing arrangement and may be coupled to the landing arrangement.

The apparatus may be configured to lock the landing arrangement when the apparatus defines the second configuration. Beneficially, this prevents the landing arrangement from inadvertently returning to the first position.

The apparatus may comprise a retaining ring, snap ring, c-ring or the like. Alternatively, the apparatus may comprise a ratchet arrangement configured to lock the landing arrangement when the apparatus defines the second configuration.

The ratchet arrangement may be formed on one or both of the piston and the mandrel.

The activation arrangement may comprise an activation arrangement.

The activation arrangement may be configured to facilitate actuation of the actuation arrangement. The activation arrangement may comprise a seat for receiving an activation device, such as a ball.

The activation arrangement may comprise a sleeve.

The seat may be formed on or coupled to the sleeve.

The sleeve may be axially moveable relative to a housing of the activation arrangement.

The sleeve may comprise or define a piston.

The activation arrangement may be disposed at a downhole location relative to the landing arrangement.

The activation arrangement may be disposed at a downhole location relative to the actuation arrangement.

In use, on landing the activation device on the seat of the activation arrangement, fluid flow through the activation arrangement is prevented, permitting fluid pressure uphole of the seat of the activation arrangement to increase. As a result of the increased applied fluid pressure, the applied fluid pressure force acting on the actuation arrangement increases. On exceeding the selected force threshold, the lock arrangement is deactivated, e.g. by shearing of the lock member(s), releasing the landing arrangement and actuation arrangement for movement relative to the mandrel.

The sleeve may be releasably coupled to the housing.

The activation arrangement may comprise a lock arrangement.

The lock arrangement may comprise one or more lock member.

The lock member, or in embodiments comprising a plurality of lock members at least one of the lock members may comprise a snap ring, retaining ring, c-ring or like.

Alternatively or additionally, the lock member, or in embodiments comprising a plurality of lock members at least one of the lock members, may comprise a shear pin, shear screw, shear disk or the like.

According to a second aspect, there is provided a downhole assembly comprising the downhole apparatus of the first aspect.

The downhole assembly may comprise or take the form of a work string or the like.

The downhole assembly may further comprise one or more of a wellbore cleaning tool, a drilling tool and/or a milling tool, reaming tool or the like.

In use, the downhole assembly may be run into the borehole, with the downhole apparatus defining the first configuration in which the landing arrangement is arranged in the radially extended position arranged to land on the seat. The seat may, for example, be formed by the top of the liner. The actuation arrangement is operable to reconfigure the downhole apparatus from the first configuration to the second configuration in which the landing arrangement defines the radially retracted position, permitting the apparatus to be run through the seat, and permitting additional operations to be carried out. Beneficially, embodiments of the apparatus permit multiple downhole operations to be carried out in a single trip. By way of example, embodiments of the apparatus permit an inflow test to be performed and subsequent wellbore cleaning, drilling out, reaming and/or milling operations to be carried out in a single trip, providing significant time savings for the operator, and with consequential and substantial cost savings.

According to a third aspect, there is provided a method of performing downhole operations using the downhole assembly of the second aspect.

The method may comprise running the assembly, e.g. work string, into the borehole.

The method may comprise engaging a seat.

The seat may be provided in or formed by the top of the liner, as described above.

The assembly may comprise a packer, such as an inflow test packer. In particular, but not exclusively, the inflow test packer may comprise a mechanical inflow test (MIT) packer or the like.

Beneficially, the downhole apparatus may act as a landing off point for the packer.

The method may comprise setting down weight to set the packer.

The method may comprise testing the packer.

The method may comprise unsetting the packer.

The method may comprise performing an inflow test.

The method may comprise slacking off weight to set the packer.

Once the inflow test has been carried out, the apparatus is then reconfigured to permit passage of the assembly through the liner.

The method may comprise picking up the downhole assembly.

The method may comprise dropping the activation device, such as a ball.

The method may comprise engaging the seat of the activation arrangement with the activation device.

Engaging the activation device with the seat may permit fluid pressure above the seat to increase. As described above, as a result of the increased applied fluid pressure, the applied fluid pressure force acting on the actuation arrangement increases. On exceeding the selected force threshold, the lock arrangement is deactivated, e.g. by shearing of the lock member(s), releasing the landing arrangement and actuation arrangement for movement relative to the mandrel.

The method may comprise drilling out cement. For example, but not exclusively, the method may comprise drilling out cement by rotating the work string.

The method may comprise performing a wellbore cleaning operation using the downhole assembly.

It will be understood that the features defined above or described below may be utilised alone or in combination with any other defined feature.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other aspects will now be described by way of example with reference to the accompanying drawings, of which:

Figure 1 shows a perspective view of a downhole apparatus;

Figure 2 shows a longitudinal sectional view of the downhole apparatus shown in Figure 1 ;

Figure 3 shows a cross sectional view along B-B of the downhole apparatus shown in Figure 2;

Figure 4 shows an enlarged view of part of the downhole apparatus shown in Figure 1 ;

Figure 5 shows an enlarged view of part of the downhole apparatus shown in Figure 1 ;

Figure 6 shows a downhole string comprising the apparatus shown in Figure 1 in a first configuration;

Figure 7 shows the downhole string comprising the apparatus shown in Figure

1 in a second configuration; and

Figure 8 shows a flow chart of a downhole operation utilising the downhole string shown in Figures 6 and 7.

DETAILED DESCRIPTION OF THE DRAWINGS

Referring first to Figure 1 of the accompanying drawings, there is shown a perspective view of a downhole apparatus 10.

As shown in Figure 1 , the apparatus 10 comprises a landing arrangement 12 and an actuation arrangement 14.

In use, and as will be described further below, the downhole apparatus 10 forms part of a downhole assembly in the form of tubing string 1000 which is run into a cased borehole B, the apparatus 10 during run in defining a first configuration in which the landing arrangement 12 is arranged in an extended position arranged to land in a seat S provided in the top of the liner to thereby support the tubing string 1000. The actuation arrangement 14 is operable to reconfigure the downhole apparatus 10 from the first configuration to a second configuration in which the landing arrangement 12 defines a radially retracted position, permitting the apparatus 10 to be run through the seat S and perform a wellbore cleaning tool, a drilling tool and/or a milling tool, reaming tool or the like.

Referring now also to Figure 2 of the accompanying drawings which shows a longitudinal sectional view of the apparatus 10, in the illustrated apparatus 10 the landing arrangement 12 comprises a collet 16 having a body 18 and a plurality of circumferentially arranged and spaced collet fingers 20 while the actuation arrangement 14 comprises an actuation piston 22. As can be seen from Figure 2, in the illustrated apparatus 10 the actuation piston 22 forms an integral part of the body 18 of the collet 16. However, it will be recognised that the actuation piston 22 may alternatively comprise a separate component.

As shown in Figures 1 and 2, the collet 16 is disposed on a mandrel 24 having a mandrel body 26 which is generally tubular in construction, having an axial flow passage in the form of axial throughbore 28.

A first end portion (left end as shown in the drawings) of the mandrel 24 - which in use forms an uphole end portion of the apparatus 10 - comprises a female connector in the form of threaded box connector 30 for connecting the apparatus 10 to an uphole component of the tubing string 1000. A second end portion (right end as shown in the drawings) of the mandrel 24 comprises a male connector in the form of threaded pin connector 32 for connecting the mandrel 24 to crossover sub 34.

As can be seen from Figure 2, the mandrel 24 defines a stepped outer surface, having a first recess portion 36 and a second recess portion 38. It can be seen that the mandrel body 26, first recess portion 36 and second recess portion 38 define three distinct outer diameters, mandrel outer diameter D1 corresponding to the drift diameter for the apparatus 10. An upper end of the first recess portion 36 is tapered and, in use, defines a fishneck profile to facilitate retrieval of the apparatus 10 where required. The first recess portion 36 supports the collet fingers 20 in their first, radially extended, position. The second recess portion 38 is disposed downhole (to the right in the drawings) of the first recess portion 36 and supports the collet fingers 20 in their second, radially retracted, position. The collet fingers 20 are heat treated so that they are biased towards the radially retracted position unless supported in the radially extended position by the mandrel 24.

Referring now also to Figure 3 of the accompanying drawings, which shows an enlarged view of part of the apparatus 10, the mandrel 24 also comprises a lateral flow passage in the form of one or more flow ports 40. The flow ports 40 extend through the mandrel body 26 and provide fluid communication between the axial throughbore 28 and the actuation piston 22 of the actuation arrangement 14.

As shown in Figure 3, seals 42 are disposed in grooves 44 in the mandrel body 26. In the illustrated apparatus 10, the seals 42 take the form of high temperature rotary seals. In the illustrated apparatus 10, the seals 42 comprise T-seals. As shown, the seals 42 are disposed either side of the flow ports 40 to as to define an isolated piston chamber 46 between the mandrel 24 and the actuation piston 22, permitting fluid communicated through the axial throughbore 28 to act on the actuation piston 22, the fluid pressure acting on the exposed area of the actuation piston 22 generating an actuation force on the actuation piston 22.

Referring now also to Figure 4 of the accompanying drawings, the apparatus 10 further comprises a lock arrangement 48 for retaining the apparatus 10 in the first configuration until the actuation force exceeds a selected force threshold. As shown, the lock arrangement 48 comprises a number of circumferentially arranged and spaced lock members in the form of shear screws 50. In the illustrated apparatus 10, the lock arrangement 48 comprises four shear screws 50. However, it will be recognised that the number, rating, and arrangement of the shear screws 50 may be adapted to provide the selected force threshold. As shown in Figure 3, the shear screws 50 are disposed within a housing 52 disposed on the mandrel 24. An uphole end portion (left end as shown in the drawings) of the housing 52 extends over a downhole end portion (right end as shown in the drawings) of the actuation piston 22, in an overlapping fashion, such that the actuation force acting on the actuation piston 22 is transmitted to the housing 52. A snap ring 54 is disposed in a groove 56 in the mandrel body 26. In use, the snap ring 54 prevents the collet 16 from inadvertently returning to the first position.

A lock ring 58 - which in use forms a housing around the snap ring - is threadedly coupled to the housing 52 via threaded connector 60, an uphole end portion (left end as shown in the drawings) of the lock ring 58 extending over a downhole end portion (right end as shown in the drawings) of the housing 52, in an overlapping fashion.

In use, when the fluid pressure and thus the actuation force on the actuation piston 22 exceeds the selected force threshold, this force is transmitted to the housing 52, shearing the shear screws 50 and permitting axial movement of the actuating piston 22 and collet 16 relative to the mandrel 24 by the actuation force, moving the collet 16 so that it no longer supported in the extended position and so snaps into the second recess portion 38.

As described above, and referring again to Figure 2 of the drawings, the second end portion (right end as shown in the drawings) of the mandrel 24 comprises a male connector in the form of threaded pin connector 32 for connecting the mandrel 24 to crossover sub 34. The crossover sub 34 is generally tubular in construction, having a body 62 and an axial flow passage in the form of axial throughbore 64. A first end portion (left end as shown in the drawings) of the crossover sub 34 comprises a female connector in the form of threaded box connector 66 for connecting to the connector 32. A second end portion (right end as shown in the drawings) of the crossover sub 34 comprises a male connector in the form of threaded pin connector 68 for connecting the crossover sub 34 to activation sub 70.

Referring now also to Figure 5 of the accompanying drawings, it can be seen that the activation sub 70 is generally tubular in construction, having a body 72 and an axial flow passage in the form of axial throughbore 74 disposed therethrough. A first end portion (left end as shown in the drawings) of the activation sub 70 comprises a female connector in the form of threaded box connector 76 for connecting to the threaded pin connector 68. A second end portion (right end as shown in the drawings) of the activation sub 70 comprises a female connector in the form of threaded box connector 78 for connecting the activation sub 70 to lower crossover sub 80.

As shown in Figure 5, a sleeve 82 is disposed in the activation sub 70, the sleeve 82 defining or providing mounting for a seat 84 configured to receive an activation device in the form of ball 86 (shown in Figure 7). As shown in Figure 5, seals 88 are disposed in grooves 90 in the sleeve 82 such that the sleeve 82 forms an axially moveable piston within the body 72. The sleeve 82 is coupled to the body 72 by a number of circumferentially arranged and spaced lock members in the form of shear pins 92.

In use, on seating the ball 86 on the seat 84, fluid passage through the apparatus 10 is stopped or restricted, increasing pressure uphole of the activation sub 70 and thereby increasing the pressure and resultant force until it exceeds the selected force threshold to actuate the actuating piston 22. The pressure also acts on the sleeve 82 via the ball 86, however the shear pins 92 prevent movement of the sleeve 82 relative to the body 72 until a second, higher, selected force threshold is exceeded. Once the second, higher, selected force threshold is exceeded, the shear pins 92 shear permitting movement of the sleeve 82 into a fluid bypass recess 94 formed in the body 72, whereby fluid may bypass around the sleeve 82.

As described above, and referring now also to Figures 6, 7 and 8 of the accompanying drawings, the apparatus 10 forms parts of downhole assembly in the form of work string 1000 which is run into a cased borehole B, the apparatus 10 during run in defining a first configuration in which the landing arrangement 12 is arranged in an extended position arranged to land on a seat S, to thereby support the work string 1000. In the illustrated work string 1000, the seat S is provided by or in the liner L, in particular at the top of liner.

In addition to the apparatus 10, the work string 1000 comprises a packer in the form of mechanical inflow test (MIT) packer 1002, a crossover sub 1004, and a drill collar space out tool 1006.

The assembly 1000 is run into the cased borehole B and engages the seat S, as shown in Figure 7.. It will be recognised that engaging the apparatus 10 with the seat 10 provides a land off for the packer 1002.

Once engaged with the seat S, the operator sets down weight to set the packer

1002..

The packer 1002 is tested, unset/released, and then lower density fluid is pumped downhole.

The packer 1002 is then set, e.g. by slacking off or applying weight.

The inflow test is then carried out.

Following completion of the inflow test, the assembly 1000 is picked up and an activation device in the form of ball 86 is dropped from surface.

On engaging the seat 84 with the activation device (as shown in Figure 7), fluid pressure increases. When the fluid pressure and thus the actuation force on the actuation piston 22 exceeds the selected force threshold, this force is transmitted to the housing 52, shearing the shear screws 50 and permitting axial movement of the actuating piston 22 and collet 16 relative to the mandrel 24 by the actuation force, moving the collet 16 so that it is no longer supported in the extended position and so snaps into the second recess portion 38 of the mandrel 24.

As described above, the pressure acts on the sleeve 82 via the ball, however the shear screws 92 prevent movement of the sleeve 82 relative to the body 72 until a second, higher, selected force threshold is exceeded.

Once the second, higher, selected force threshold is exceeded, the shear screws 92 shear permitting movement of the sleeve 82 into a fluid bypass recess 94 formed in the body 72, whereby fluid may bypass around the sleeve 82.

The wellbore cleaning operation, e.g. a drill out, reaming and/or milling operation, may then be carried out.

It will be understood that various modifications may be made without departing from the scope of the claims.

Claims

1. A downhole apparatus comprising:

a landing arrangement for engaging a seat; and

an actuation arrangement operatively associated with the landing arrangement, wherein the actuation arrangement is configured to reconfigure the apparatus from a first configuration in which the landing arrangement defines an extended position and a second configuration in which the landing arrangement defines a radially retracted configuration.

2. The downhole apparatus of claim 1 , wherein the landing arrangement comprises a collet.

3. The downhole apparatus of claim 2, wherein the collet comprises collet fingers, the collet fingers being radially extended in the first configuration and the collet fingers being radially retracted in the second configuration.

4. The downhole apparatus of claim 2 or 3, wherein the collet is biased towards the second, radially retracted, position.

5. The downhole apparatus of any preceding claim, comprising a mandrel configured to support the landing arrangement in the first configuration and in the second configuration.

6. The downhole apparatus of claim 5, wherein the landing arrangement is axially moveable relative to the mandrel to reconfigure the apparatus from the first configuration to the second configuration.

7. The downhole apparatus of any preceding claim, wherein the landing arrangement comprises a lock arrangement.

8. The downhole apparatus of claim 7, when dependent on claim 5, wherein the lock arrangement is configured to releasably lock the landing arrangement to the mandrel.

9. The downhole apparatus of claim 7 or 8, wherein the lock arrangement comprises one or more shearable lock member.

10. The downhole apparatus of any preceding claim, wherein the actuation arrangement is operable in response to an applied fluid pressure force.

1 1 . The downhole apparatus of claim 10, wherein the actuation arrangement comprises a piston operable in response to the applied fluid pressure force exceeding a selected force threshold.

12. The downhole apparatus of any preceding claim, wherein the apparatus comprises an activation arrangement, the activation arrangement comprising:

a sleeve; and

a seat formed on or coupled to the sleeve.

13. The downhole apparatus of claim 12, wherein the sleeve comprises or defines a piston.

14. The downhole apparatus of 13, wherein the sleeve is releasably coupled to the housing, the activation arrangement comprising a lock arrangement.

15. The downhole apparatus of claim 14, wherein the lock arrangement comprises one or more shearable lock member, such as a shear screw.

16. A downhole assembly comprising the downhole apparatus of any preceding claim.

17. The downhole assembly of claim 16, comprising a packer.

18. The downhole assembly of claim 17, wherein the packer comprises an inflow test packer.

19. A method of performing downhole operations in a single trip using the downhole assembly of claims 16, 17 or 18.

20. The method of claim 19, wherein the downhole operations comprise: an inflow test; and a wellbore cleaning, drilling, reaming and/or milling operation.