Well tool device for opening and closing a fluid bore in a well

Abstract

A well tool device includes a housing having an axial through bore; a sleeve section axially displaceable relative to the housing; a fluid flow preventing frangible disc; and an axial fluid passage bypassing the frangible disc when the well tool device is in an initial state, thereby allowing a fluid flow between a first location above the frangible disc and a second location below the frangible disc. The sleeve section includes an axial through bore aligned with the axial through bore of the housing. The axial fluid passage is closed when the well tool device is in a intermediate state. The fluid flow preventing frangible disc is provided in the bore of the sleeve section in sealing engagement with the sleeve section. The well tool device further includes a disc supporting device for supporting the frangible disc in relation to the sleeve section. The disc supporting device is releasably connected inside the sleeve section by a releasable connection device. The well tool device further includes a disintegration device disintegration of the frangible disc. The well tool device is in a final state when the frangible disc has been disintegrated by the disintegration device. The frangible disc is configured to be pushed axially relative to the sleeve section towards the disintegration device after release of the disc supporting device.

Claims

1. A well tool device comprising: a housing having an axial through bore; a sleeve section axially displaceable relative to the housing, wherein the sleeve section comprises an axial through bore aligned with the axial through bore of the housing; a fluid flow preventing frangible disc; and an axial fluid passage bypassing the frangible disc when the well tool device is in an initial state, thereby allowing a fluid flow between a first location above the frangible disc and a second location below the frangible disc; wherein the axial fluid passage is closed when the well tool device is in an intermediate state; the fluid flow preventing frangible disc is provided in the bore of the sleeve section in sealing engagement with the sleeve section; the well tool device further comprises a disc supporting device for supporting the frangible disc in relation to the sleeve section, wherein the disc supporting device is releasably connected inside the sleeve section by means of a releasable connection device; the well tool device further comprises a disintegration device for disintegration of the frangible disc, wherein the well tool device is in a final state when the frangible disc has been disintegrated by means of the disintegration device; the disintegration device is fixed to the sleeve section on a same side of the frangible disc as the disc supporting device; and the frangible disc is configured to be pushed axially relative to the sleeve section towards the disintegration device after release of the disc supporting device.

2. The well tool device according to claim 1, further comprises a sleeve locking system for preventing relative axial displacement between the housing and the sleeve section when the well tool device is in the intermediate state.

3. The well tool device according to claim 2, wherein the sleeve locking system comprises: a first recess provided in the bore of the housing; a second recess provided in an outer surface of the sleeve section, wherein the first and second recesses are axially aligned in the intermediate state; and a pre-tensioned locking device provided in the first or second recess, wherein the locking device is configured to lock the first and second recesses to each other in the intermediate state.

4. The well tool device according to claim 1, further comprises a first actuating system for moving the sleeve section axially in relation to the housing from the initial state to the intermediate state.

5. The well tool device according to claim 4, wherein the first actuating system comprises: a valve control system; a valve controlled by the valve control system; a first fluid line provided between the bore and the valve; a piston axially displaceable within a piston cylinder; and a second fluid line provided between a first side of the piston and the valve; wherein: a second side of the piston is connected to the sleeve section; the valve is preventing fluid flow between the bore and the first side of the piston in the initial state; and the valve is allowing fluid flow between the bore and the first side of the piston in the intermediate state, thereby causing linear movement of the piston within the piston cylinder and hence axial movement of the sleeve section.

6. The well tool device according to claim 1, wherein: the housing comprises a first stop profile within the bore; the sleeve section comprises a second stop profile on its outer surface; wherein the second stop profile is engaged with the first stop profile in the intermediate state.

7. The well tool device according to claim 1, further comprises a second actuating system for releasing the releasable connection device, thereby causing a release of the disc supporting device from the sleeve section.

8. The well tool device according to claim 7, wherein the second actuating system comprises: a valve control system; a valve controlled by the valve control system; a first fluid line provided between the bore and the valve; a piston axially displaceable within a piston cylinder; and a second fluid line provided between a first side of the piston and the valve; wherein a second side of the piston is connected to the releasable connection device; the valve is preventing fluid flow between the bore and the first side of the piston in the initial state and intermediate state; and the valve is allowing fluid flow between the bore and the first side of the piston to initiate the final state, thereby causing linear movement of the piston within the piston cylinder and hence release of the releasable connection device.

9. The well tool device according to claim 8, wherein the second actuating system and the releasable connection device are provided on opposite sides of the frangible disc.

10. The well tool device according to claim 8, wherein a piston rod in one end is connected to the second side of the piston, and in a second end is provided in contact with an actuating rod of the releasable connection device.

11. The well tool device according to claim 10, wherein the actuating rod is provided in an axial bore provided in the sleeve section.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) Embodiments of the invention will now be described in detail, with reference to the enclosed drawings, where:

(2) FIG. 1 illustrates a cross sectional view of the well tool device in an initial state;

(3) FIG. 2 illustrates a cross sectional view of the well tool device in an intermediate state;

(4) FIG. 3 illustrates a cross sectional view of the well tool device in a first phase of a final state;

(5) FIG. 4 illustrates a cross sectional view of the well tool device in a second phase of the final state;

(6) FIG. 5 illustrates an enlarged view of FIG. 1;

(7) FIG. 6 illustrates an enlarged view of FIG. 2;

(8) FIG. 7 illustrates an enlarged view of FIG. 3.

DETAILED DESCRIPTION

(9) It is now referred to FIG. 1-4. In FIG. 1-4, the left side of the drawings are facing towards the upper side of the well, while the right side of the drawings are facing towards the lower side of the well. In FIG. 5-7, the upper side of the drawings are facing toward the upper side of the well, while the lower side of the drawings are facing towards the lower side of the well.

(10) A well tool device 1 is generally referred to with reference number 1. In FIGS. 1 and 5, the well tool device 1 is in an initial state S1. In FIGS. 2 and 6, the well tool device 1 is in an intermediate state S2. In FIGS. 3 and 7, the well tool device 1 is in a first phase of a final state S3, while in FIG. 4, the well tool device 1 is in a second phase of the final state S3. These states S1, S2 and S3 will be described in detail together with the well tool device 1 below.

(11) The well tool device 1 comprises an outer housing 10 with an axial through bore 11. The well tool device 1 comprises an upper connection interface 13a and a lower connection interface 13b for connection to a completion pipe, production tubing etc. These connection interfaces 13a, 13b may be threaded connection interfaces, or other types of connection interfaces. The axial through bore 11 has a diameter D11 which is typically equal to the inner diameter of the completion pipe, production tubing etc.

(12) A longitudinal central axis II of the well tool device 1 is indicated in FIGS. 2 and 3.

(13) One section 11s of the axial through bore 11 has a larger diameter D11a than the diameter D11. This section 11a forms a compartment for a sleeve section 20. The sleeve section 20 is axially displaceable relative to the housing 10. The sleeve section 20 comprises an axial through bore 21 aligned with the axial through bore 11 of the housing 10. The axial displacement of the sleeve section 20 is limited by the length of the section 11a of the bore 11. In FIG. 1, it is shown that the housing 10 comprises a first stop profile 16 within the bore 11. This first stop profile 16 forms the border between the bore 11 and the bore 11a. The sleeve section 20 comprises a second stop profile 26 on its outer surface, where the second stop profile 26 is engaged with the first stop profile 16 in the intermediate state S2.

(14) In addition, the axial displacement of the sleeve section 20 is limited by a sleeve locking system 4, which will be described more in detail below.

(15) The axial through bore 21 has an inner diameter D21 which is equal to the diameter D11 of the bore 11. Hence, the sleeve section 20 itself does not limit fluid flow through the well tool device 1 substantially.

(16) The well tool device 1 further comprises a fluid flow preventing frangible disc 30 provided in the bore 21 in sealing engagement with the sleeve section 20. As is known from prior art, the frangible disc 30 is typically made of hardened glass, and is shaped as a cylinder with chamfered upper and lower edges. These chamfered upper and lower edges are supported in a so-called seat in the sleeve section 20. In FIG. 5, it is shown that an o-ring 32 is provided radially between the frangible disc 30 and the sleeve section 20. Hence, as long as the disc 30 is present in the sleeve section 20, axial fluid flow through the bore 21 of the sleeve section 20 is prevented.

(17) As shown in FIG. 5, o-rings 36 is also provided radially between the sleeve section 20 and the housing 10, i.e. radially outside of the sleeve section 20 and radially inside of the housing 10. These o-rings 36 prevents axial fluid flow through the bore 11 and bore 11a, on the outside of the sleeve section 20. The o-rings 36 are axially displaced at a distance D36 above the o-ring 32 of the disc 30. In FIG. 6, it is shown that the o-ring 32 is axially (vertically in FIG. 5) aligned with the o-rings 36.

(18) The axially displaceable sleeve section 20 can be releasably connected to the housing 10 in the first state S1. This connection could be provided by a shear pin (not shown), which are sheared off at a predetermined load.

(19) Devices 40, 41 and 42

(20) In the present embodiment, the well tool device 1 comprises a disc supporting device 41 for supporting the frangible disc 30 in relation to the sleeve section 20. The upper chamfered edge of the disc 30 and the side surface of the disc 30 are supported by the sleeve section 20, while the lower chamfered edge of the disc 30 is supported by the upper supporting surface 41a of the disc supporting device 41. Hence, when the disc supporting device 41 is removed, nothing prevents the disc 30 from being pushed axially downwards in relation to the sleeve section 20. When comparing FIGS. 6 and 7, it is shown that the disc supporting device 41 can be moved downwardly a distance D41 with respect to the sleeve section 20, corresponding to a distance between the lower end of the disc supporting device 41 and a stop 28 provided as part of the sleeve section 20.

(21) The disc supporting device 41 is releasably connected inside the sleeve section 20 by means of a releasable connection device 42. The releasable connection device 42 is a cycle actuated mechanism described in prior art EP2978926B.

(22) The well tool device 1 further comprises a disintegration device 40 for disintegration of the frangible disc 30. The disintegration device 40 is fixed to the sleeve section 20, within the bore 21 and is located at a short distance below the frangible disc 30. The disintegration device 40 is provided at a distance below frangible disc 30 which is shorter than the distance D41. Hence, when the disc supporting device 41 is released from the sleeve section 20, the disc 30 may be pushed downwardly into contact with the disintegration device 40, thereby causing disintegration of the disc 30.

(23) Axial Fluid Passage 2

(24) In FIG. 1 and FIG. 4, it is shown that the well tool device 1 comprises an axial fluid passage 2, allowing fluid to bypass the frangible disc 30. This bypass fluid flow is indicated by arrow FF1 between a first location L1 above the frangible disc 30 and a second location L2 below the frangible disc 30. It should be noted that FF1 is bidirectional, i.e. fluid may flow from the first to the second location and from the second to the first location, dependent on the fluid pressure on the respective sides of the disc 30.

(25) In FIG. 5, it is shown that the axial fluid passage 2 comprises first and second fluid lines 22a, 22b provided in a radial direction through the sleeve section 20, i.e. from the bore 21 on the inside of the sleeve section 20 to the bore 11 or 11a of the housing 10 outside of the sleeve section 20. The first fluid line 22a is located above the disc 30, and the second fluid line 22b is located below the disc 30. In addition, the axial fluid passage 2 comprises a third fluid line 12 provided as an axial recess in the housing 10. The third fluid line 12 provides fluid communication between the first and second fluid lines 22a, 22b. Hence, as shown in FIG. 5, fluid is allowed to flow from the first location L1, through the first fluid line 22a, through the third fluid line 12, through the second fluid line 22b and then to the second location L2. As mentioned above, fluid flow in the opposite direction is also possible. From FIG. 5 it is apparent that the well tool device 1 comprises several such axial fluid passages 2 spaced apart from each other circumferentially around the sleeve section 20 and housing 10.

(26) Hence, in the initial state S1 of FIGS. 1 and 5, the well tool device 1 is said to be open, as fluid flow through the device 1 is allowed via the axial fluid passage 2 bypassing the frangible disc 30.

(27) First Actuating System 50 and Second Actuating System 60

(28) The well tool device 1 comprises a first actuating system 50 and a second actuating system 60, shown in FIG. 1. The first and second actuating systems 50, 60 are provided in the housing 10, for example within a compartment of the housing 10. The first actuating system 50 is provided in the lower part of the housing 10, while the second actuating system 60 is located in the upper part of the housing 10.

(29) The first actuating system 50 comprises a valve control system 51 for controlling a valve 52. The first actuating system 50 further comprises a piston 54 axially displaceable within a piston cylinder 55. A first, lower, side of the piston 54 is faced towards the valve 52, while a second, upper, side of the piston 54 is faced towards the sleeve section 20.

(30) A first fluid line 53a is provided between the bore 11 and the valve 52. A second fluid line 53b is provided between the valve 52 and the lower part of the piston 54. Hence, the first side of the piston 54 is provided in fluid communication with the valve 52. The second side of the piston 54 is connected to the sleeve section 20 by means of a rod 56.

(31) The valve 54 can be controlled to be in two different positions, a first position in which the valve 54 is preventing fluid flow between the first and second fluid lines 53a, 53b and a second position in which the valve 54 is allowing fluid flow between the first and second fluid lines 53a, 53b.

(32) The second actuating system 60 comprises a valve control system 61 for controlling a valve 62. The second actuating system 60 further comprises a piston 64 axially displaceable within a piston cylinder 65. A first, upper, side of the piston 64 is faced towards the valve 62, while a second, lower, side of the piston 64 is faced towards the sleeve section 20.

(33) A first fluid line 63a is provided between the bore 11 and the valve 62. A second fluid line 63b is provided between the valve 62 and the lower part of the piston 64. Hence, the first side of the piston 64 is provided in fluid communication with the valve 62. The second side of the piston 64 is connected to a piston rod 66. The piston rod 66 is used to release the connection device 42. In FIG. 2, it is shown that the piston rod 64 is provided in contact with an actuating rod 43 of the releasable connection device 42. The actuating rod 43 is provided in a compartment within the sleeve section 20.

(34) The valve 64 can be controlled to be in two different positions, a first position in which the valve 64 is preventing fluid flow between the first and second fluid lines 63a, 63b and a second position in which the valve 64 is allowing fluid flow between the first and second fluid lines 63a, 63b.

(35) The valve control system 51 may comprise an electric actuator for controlling the valve 52. The electric actuator can control the valve 52 to open at a predetermined time by using a timer, at a signal detected by a sensor, for example a signal in the form of hydraulic pulses detected by a pressure sensor, electromagnetic signals detected by an antenna etc. In the present embodiment, pressure pulses are detected by the valve control system 51 via openings 59 to the bore 11. In similar way, the valve control system 61 of the second actuating system 60 detects pressure pulses via openings 69 to the bore 11.

(36) It should be noted that the number of pulses needed for the valve control system 51 to actuate the valve 52 is different than the number of pulses needed to actuate the valve 62, as the first actuating system 50 should be actuated before the second actuating system 60.

(37) It should also be noted that the pressure within the fluid cylinders 55, 65 on the second side of the pistons 54, 64, i.e. on the upper side of piston 54 and on the lower side of piston 64, is lower or substantially lower than the expected well pressure in the well. Such a lower or substantially lower pressure can be a so-called atmospheric pressure as discussed in the introduction above.

(38) The Sleeve Locking System 4

(39) The sleeve locking system 4 mentioned above will now be described with reference to FIGS. 1 and 2. The sleeve locking system 4 comprises a first recess 14 provided in the bore 11 of the housing 10, a second recess 24 provided in an outer surface of the sleeve section 20 and a pre-tensioned locking device 34 provided in the first or second recess 14, 24. In the present embodiment, the pre-tensioned locking device 34 is a pre-compressed locking ring or a so-called snap ring, which in the initial state S1 is provided in the second recess 24.

(40) In FIG. 1, the first and second recesses 14, 24 are provided axially displaced from each other. In FIG. 2, the first and second recesses 14, 24 are axially aligned with each other. Here, the locking ring expands partially into the first recess 14 and hence prevents relative axial movement between the housing 10 and the sleeve section 20.

(41) Operation of the Well Tool Device

(42) The operation of the well tool device 1 will now be described.

(43) In the initial state S1 of FIGS. 1 and 5, bidirectional fluid flow FF1 is allowed through the device 1. In this state, fluids in the wellbore can be replaced.

(44) When desired, the well tool device 1 can be actuated to its intermediate state S2. In the present embodiment, this is done by changing the pressure in bore 11 in a predetermined pattern, such as by cycling the pressure a predetermined number of times. This will actuate the valve control system 51 of the first actuating system 50, causing the valve 52 to rotate and allowing the fluid in the bore 11 to enter the piston cylinder 55 on the first side of the piston 54, which again will cause the piston 54 to push the sleeve section 20 upwardly by means of the piston rod 56.

(45) The sleeve section 20 will move upwardly until the second stop profile 26 contacts or engages the first stop profile 16, as indicated by the distance D36. When the sleeve section 20 is in this position, the first and second recesses 14, 24 are axially aligned with each other, and the sleeve locking system 4 provides that the sleeve section 20 is axially locked to the housing 10. The well tool device 1 is now in the intermediate state. It should be noted that it is not possible to move the sleeve section 20 downwardly again, as the sleeve locking system 4 will prevent such movement.

(46) As shown in FIGS. 2 and 6, the axial fluid passage 2 is now closed. As described above, the o-rings 32 and 36 are axially aligned. Now, the o-rings 36 are located between the first and third fluid lines 22a, 22b.

(47) In this intermediate state, the actuating rod 43 is moved together with the sleeve section 20 to a position where the actuating rod 43 is in contact with the piston rod 66 of the second actuating system 60.

(48) In this intermediate state, the completion string or tubing string above the well tool device can be pressure tested.

(49) When desired, the well tool device 1 can be actuated to its final state S3. In the present embodiment, this is done in two substeps. The first substep is to change the pressure in bore 11 (above the disc 30) in a predetermined pattern, such as by cycling the pressure a predetermined number of times. This will actuate the valve control system 61 of the second actuating system 60, causing the valve 62 to rotate and allowing the fluid in the bore 11 to enter the piston cylinder 65 on the first side of the piston 64, which again will cause the piston 64 to push the actuating rod 43 downwardly by means of the piston rod 66

(50) This will again release the releasable connection device 42, causing that the disc supporting device 41 becomes released from the sleeve section 20.

(51) The second substep is to increase the pressure above the disc 30, in order to push the disc 30 downwardly towards the disintegration device 40. As the disc supporting device 41 is released, the disc supporting device 41 will be pushed downwardly with the disc 30.

(52) As the disc 30 comes into contact with the disintegration device 40, the disc will disintegrate as shown in FIGS. 3 and 7 into small fragments, which will be transferred with the well flow.

(53) In FIG. 4, the final state S3 is shown, where a second bidirectional fluid flow FF2 is indicated. As described above, the inner diameter of the well tool device 1, indicated by diameters D11 and D21, can be equal to the inner diameter of the string being connected to the well tool device 1. Hence, the well tool device 1 does not represent a fluid restriction in the string in the final state S3. In the third state S3, the well tool device 1 allows full production through the bores 11, 21.

(54) In the description above, the sleeve section 20 is moved upwardly from the first state S1 to the intermediate and closed state S2. This is an advantage, as in this closed state, the first stop profile 16 of the housing in contact with the second stop profile 26 of the sleeve, where it is relatively easy to dimension these profiles to withstand the expected well pressure. If the sleeve section 20 was to move downwardly from the initial to the closed state, the locking mechanism for locking the sleeve section in the closed state must be dimensioned and tested to handle the expected well pressure—which may be difficult to obtain.

(55) Another advantage is that if there is a failure in the first actuating system 50, it will still be possible to close the well tool device 1. This can be performed by increasing the pressure in the entire well, i.e. increasing the pressure above and below the disc 30 (typically increasing the pressure towards the production packer). Then, the pressure can be bled off from the top side, causing the pressure to be higher below the disc 30 than above the disc 30. This pressure difference over the axial fluid passage 2 will then be so large that the sleeve section 20 will be pushed upwardly by means of the differential pressure over the axial fluid passage 2.

ALTERNATIVE EMBODIMENTS

(56) It should be noted that in case the well tool device 1 is intended to be provided in the bottom end of a completion pipe, the lower connection interface 13b may be used for connection to a mule shoe or a wireline re-entry guide.

(57) The enlarged section 11a of the bore 11 is not essential for the present invention. The axial displacement of the sleeve section 20 can be limited by other types of stops causing an engagement between the sleeve section 20 and the housing 10. However, without the enlarged section 11a, it is assumed that the diameter D21 of the sleeve section 20 would have to be substantially smaller than the diameter D11 of the bore 11.

(58) The pistons 54, 64 are described above to be mechanically connected to the sleeve section 20 and the actuating rod 43 respectively. It should be noted that a further piston can be provided in the fluid cylinder or in fluid communication with the fluid cylinder, where the further piston is connected to the sleeve section 20. In such a case, the pistons 54, 64 can be considered to be hydraulically connected to the sleeve section 20 and the actuating rod 43 respectively.