A release mechanism

Abstract: A release mechanism is described for releasing a lock member (10) which secures a first body member (5) to a second body member (1). The release mechanism comprises a reciprocal member (6) which is mounted on the first body member (5) for movement relative to the first body member (5). A catch mechanism (8, 11, 12) is also provided which is movable between the first position where the lock member (10) is fixed and the second position where the lock member (10) is released. The reciprocal member (6) moves in a first direction when a force is applied to the reciprocal member (6) and moves in a second direction when the force is removed. Repeated reciprocal movement of the reciprocal member (6) in the first and second directions effects movement of the catch mechanism (8, 11, 12) from the first position to the second position to release the lock member (10) to permit relative movement between the first and second body members (5, 1).

Description: The invention relates to a downhole tool incorporating a release mechanism. In the oil and gas recovery industry there are many operations that are done to a well during its lifetime. All oil or gas wells have equipment associated therein which requires regular maintenance. To carry out this maintenance, "plugs" have to be installed at various depths in the well by wireline operations to make the well safe. All plugs have to be designed to hold pressure differentials in both directions, firstly pressure from below, that is well build up pressure, and secondly pressure from above, that is equipment above the plug, will be pressure tested by pressurising against the plug. It is essential however that the pressure is equalised around the plug prior to retrieving the plug. To accomplish this equalisation, conventional plugs require a wireline run in the well to manipulate the plug's "equalisation device". Once equalised a second wireline run is required to retrieve the plug. One attempt at overcoming the problem of having to make two wireline runs has been to incorporate a shear pin into the internal mechanism of the plug so that when the pressure on the upper section of the plug is for example, 13.79 bar (200 psi) greater than the pressure below the plug the shear pin breaks and the mechanism is released to enable equalisation to take place. However, this solution has the problem that there are very wide tolerance margins in the shear pins which means that it may be necessary to use a pressure differential which is substantially greater than 13.79 bar (200 psi) in order to shear the pin. In addition, in order to shear the pin it may be necessary to exceed the safe working pressure of the well pipe and christmas tree located above the plug. This is often the case especially if the seals on the christmas tree and well pipe have been tested to their operational maximum limit and this is similar to the well build up pressure below the plug. A further problem with the shear pin mechanism may occur if a live well is plugged deep with such a mechanism while drilling another well. If the well being drilled accidentally breaches the plugged well, drilling mud will enter the plugged well above the plug. The weight of the drilling plug falling onto the plug with a shear pin mechanism in the live well could be sufficient to shear the pin accidentally. Clearly such a situation is undesirable during drilling as the pressure below the plug is released into both wells when the pin shears. US-A-4,474,242 discloses a downhole tool for use in a gas or oil well, which has a flow channel initially closed by a valve member. The valve member is operable by a mechanism which comprises a locking member initially in a first position in which the valve member is closed, a reciprocable piston member acted on by well fluid pressure and biased against well fluid pressure, and unidirectional drive means coupled to the piston member, such that repeated reciprocation of the piston member by repeated application of well fluid pressure moves the unidirectional drive means to a release position in which the locking member and the valve member may be moved to open the flow channel. This prior art tool is concerned with the field of drill stem testing, and is not applicable to the field of plugs used in connection with locks engaged and sealed in landing nipples. The prior art tool is adapted for equalising pressure between a well bore and a well annulus, as opposed to the regions above and below a landing nipple. Moreover, the structure of the prior art tool is such that it must use an element ruptured by a given high pressure, such as a bursting disc or a shear pin, to initiate the reciprocating action. The present invention is characterised by the following features:- the tool is a plug for closing a bore through a lock engaged and sealed in a landing nipple; the flow channel in the tool, in use, connects the lock bore to the well below the plug; the unidirectional drive means acts between the piston member and the locking member and comprises a catch which holds the locking member in said first position until the piston member has undergone a number of reciprocations to cause the catch to move to the release position in which the locking member is free to move out of engagement with a formation on the inner wall of the main body to allow sliding movement of an intermediate member with respect to the main body, which sliding movement in turn permits movement of the valve member past the flow channel; the piston member comprises an elongate member having an end face exposed to well pressure in the plug bore; and the valve member encircles the piston member and has an end face which is exposed to well pressure in the lock bore. Preferably, the piston member is arranged axially and the valve member is concentric therewith. The unidirectional drive means may comprise a first ratchet mechanism acting between the piston member and the catch and a second ratchet mechanism acting between the catch and a stationary part of the tool. Preferably, one ratchet mechanism permits movement in a first direction and grips in a second direction and the other ratchet mechanism grips in the first direction and permits movement in the second direction. The piston member is biased against well fluid pressure preferably by spring means. Optionally, the tool may also have a valve spring means exerting a biasing force urging the valve member to its open position. Examples of a tool in accordance with the invention will now be described with reference to the accompanying drawings, in which:- Fig.1 is a partial cross section of a first example of a plug for use in an oil or gas well; Fig.2 is a schematic view of how the plug shown in Fig.1 may be used to isolate a lower section of the well from an upper section; Fig.3 is a schematic diagram showing one application of the apparatus shown in Fig.1; Fig.4 is a partial cross-sectional view through a second example of a plug; and, Fig.5 is a partial cross-sectional view through a third example of a plug. Fig 1 shows a plug 20 suitable for using in an oil or gas well and which is designed to hold pressure differentials in both directions. The plug 20 has a main body 1 and a bottom sub 13 connected by a screw thread connection 40 to one end of the main body 1 and secured to the main body 1 by a grub screw 15. The main body 1 also has four flow ports 16 which enable fluid to flow from the outside of the main body 1 to the interior of the main body 1. Mounted on the main body 1 is an inner body 5 which is connected at one end by a screw thread 41 to a cap 4 also mounted within the main body 1. The cap is secured to the inner body 5 by a grub screw 15. At the other end of the inner body 5 are located a number of trip keys 10 (only one shown) which engage with a shoulder 17 on the inside on the main body 1. Mounted within the cap 4 and the inner body 5 is a reciprocator shaft 6. A bellville spring stack 7 is mounted between the inner body 5 and the reciprocator shaft 6 and biases the reciprocator shaft 6 to the position shown in Fig 1. Located at the other end of the reciprocator shaft 6 is a buttress thread 18 which engages with a rachet 8 which is located at one end of a release mandrel 11. The rachet 8 has a rachet spring ring 9 which maintains the rachet 8 in engagement with the buttress thread 18. The release mandrel 11 also has a thrust section 19 which, in the position shown in Fig 1 forces the trip keys 10 into engagement with the shoulder 17 in the main body 1. The release mandrel 11 also has a recessed section 21 and at the end opposite the end with the rachet 8 has a buttress thread 22 which engages with a rachet 12 mounted on the bottom sub 13. The rachet 12 also has a spring ring 9 which holds the rachet 12 in engagement with the buttress thread 22. In addition, two O-ring seals 2,3 seal the cap 4 with respect to the main body 1 and the cap 4 to the reciprocator shaft 6 respectively. At the other end of the main body 1 to the end with the bottom sub 13 is connected a lock 23 which is shown in phantom in Fig 1. Fig 2 shows the plug 20 connected to the lock 23. The lock 23 is engaged with a landing nipple 24a which is connected between two sections of pipe 25a,25b in an oil or gas well. As can be seen in Fig 2, the lock 23 has a lock element 26 which engages with a corresponding recess 27 in the landing nipple 24a to lock the lock 23 and plug 20 in position within the landing nipple 24a. The lock 23 also has a set of seals 28 which engage with a corresponding sealing surface 29 on the landing nipple 24a. The plug 20 seals a through bore 30 in the lock 23. Hence, the combination of the plug 20 and the seals 28 isolates the upper section of drill pipe 25a from the lower section 25b. Fig 3 shows a typical production well which has a number of pipe sections 25a to 25e which are separated by landing nipples 24a to 24d. At the top of the pipe section 25a is a christmas tree 31 from which the oil or gas produced by the well is extracted. During the lifetime of the well it may be necessary to replace the christmas tree 31 and/or to pressure test seals 32 which connect the christmas tree 31 to the upper pipe 25a. In order to do this it is necessary to block the well at a lower point to contain the pressure in the well which may be as high as 689.5 bar (10,000 psi) but which is normally around 344.75 bar (5,000 psi). To seal the well the plug 20 is connected to the end of the lock 23 and the lock 23 and plug 20 are dropped into the well by a wireline operation so that the lock elements 26 on the lock 23 engage with the lock recess 27 in one of the landing nipples 24a to 24d. For the purposes of this example it is assumed that the lock 23 is engaged with landing nipple 24a. When the lock 23 and plug 20 are in position the plug 20 and seals 28 isolate the upper section 25a of the well from the lower section 25b and the pressure in the upper section 25a of the well can be released to enable the christmas tree 31 to be removed from the upper section 25a. When the christmas tree 31 is replaced on the section 25a the seals 32 must be checked in order to ensure that they do not leak and normally this is done by pumping sea water into the upper section 25a of the well, above the lock 23 and plug 20, up to the working pressure of the well. When the upper section 25a of the well is pumped up to working pressure the pressure of the sea water within the upper section of the well 25a will exert a pressure on an end surface 33 or the reciprocal shaft 6 in the plug 20. This causes the reciprocal shaft 6 to move a distance x (see Fig.1) against the action of the bellville spring stack 7 which in turn causes the buttress thread 18 to move a distance x relative to the rachet 8. When the pressure within the upper section of the well 25a is released the reciprocator shaft 6 will return to the position shown in Fig 1 and the buttress thread 22 will be moved relative to the rachet 12 by the distance x, and the rachet 8 will grip the buttress thread 18 to prevent relative movement between the reciprocator shaft 6 and the release mandrel 11. Hence, the thrust section 19 of the release mandrel 11 moves relative to the trip key 10 by the distance x. After the pressure testing of the seals 32 has been completed the thrust section 19 of the release mandrel 11 will have moved relative to the trip key 10 due to the action on the rachets 8,12 on the buttress threads 18,22 respectively. However, the thrust section 19 will still be in engagement with the trip key 10 to maintain the trip key 10 against the shoulder 17 in the main body 1. In order to remove the lock 23 and plug 20 from the landing nipple 24a it is first necessary to allow the well to equalise the pressure between the two pipe sections 25a and 25b. If this is not done then when the lock elements 26 are released the lock 23 and plug 20 will be forced up the well by the pressure in the pipe section 25b and due to the high pressures within the pipe section 25b this is of course very dangerous. Hence, in order to equalise the pressure between the pipe sections 25a and 25b in order to enable the lock 23 and plug 20 to be safely removed from the landing nipple 24a pressure in the upper section 25a is increased and decreased repeatedly in order to obtain reciprocal movement of the reciprocator shaft 6 which draws the release mandrel 11 to the left, as shown in fig 1. When the release mandrel 11 has been drawn far enough to the left the thrust section 19 will have moved to the left of the trip key 10 and so the trip key 10 may move in to the recessed section 21 of the release mandrel 11. This takes the trip key 10 out of engagement with the shoulder 17 and permits the inner body 5 to move towards the bottom sub 13 of the plug 20. This permits the flow ports 16 to communicate with the through bore 30 in the lock 23 which enables fluid in the pipe section 25b to communicate with fluid in the pipe section 25a in order to enable the pressure to be equalised across the pipe sections 25a, 25b. When the pressures have been equalised the lock 23 and plug 20 can be removed by a wireline operation in a conventional manner. As the equalisation mechanism of the plug 20 relies on movement in response to pressure it can be seen that pressure less than the maximum operating pressure of the section 25a, christmas tree 31 and the seals 32 can be used to operate the equalisation mechanism. This avoids the need to either exceed the safe working pressure of these components and also avoids the need for two wireline operations, one operation to operate the equalisation mechanism and the second operation to retrieve the lock 23 and plug 20 after equalisation has taken place. It can be seen that the mechanism disclosed here can be easily designed so that the equalisation mechanism will trigger after the predetermined number of pressure cycles by for example choosing an appropriate distance x with respect to the length of the thrust section 19 on the release mandrel 11 or by varying the size of the bellville spring stack 7 so that, for example, at low pressure the reciprocator shaft 6 does not travel the full distance x. As can be seen some of the advantageous features of the release mechanism in the plug 20 is that it enables high pressure tests to be carried out above the lock 23 and plug 20 but enables the flow port 16 to be opened by using a relatively low pressure. It is also possible to adjust the size and frequency of the pressure cycles necessary to open the flow ports and when the flow ports are opened there is a large flow of area. Figs 4 and 5 show two additional examples of plugs 40, 50 for use in an oil or gas well. Fig 4 shows a plug 40 which is similar to the plug 20 but which has a number of modifications. Components which are similar to the components of the plug 20 have the same reference numerals as used in Fig 1. In the plug 40, the inner body 5 has a thread 44 on its outside surface and a threaded spring retainer ring 43 is threaded onto the thread 44. In addition, the main body 1 is formed from two sections 46, 47 which are interconnected by a thread 48 and secured by a grub screw 49. A helical spring 42 is located in the annular gap between the inner body 5 and the outer body section 47 and is compressed between the spring retainer ring 43 and an end of the body section 46. The helical spring 42 aids movement of the inner body 5 towards the bottom sub 13 when the trip key 10 moves out of engagement with the shoulder 17. In the plug 40 the shoulder 17 is formed on a removable insert 41 and this reduces the likelihood of damage occurring to the body section 47 and also makes the shoulder 17 easier to machine. In addition, a shock absorbing O-ring 50 is located between the bottom sub 13 and the release mandrel 11. The O-ring 50 helps absorb jarring shocks applied to the plug 40 when jarring operations are used to set the plug 40 in the oil or gas well. The plug 60 shown in Fig.5 is similar to the plug shown in Fig.4 and similar sections have been indicated using the same reference numerals. The main difference between the plug 40 in Fig.4 and the plug 60 in Fig.5 is that the plug 60 has an adaptor 61 attached to its top end where the lock 23 would normally be connected to the plugs 20, 40. In this example the lock 23 would be connected onto the adaptor 61 by means of the thread 62. O-rings 63 seal the adaptor 61 to the upper body section 46 of the plug 60 and to a cap 64. The cap 64 is attached to the body section 5 in a similar manner as the cap 4 is attached to the body section 5 in the plugs 20, 40. However, the cap 64 differs from the cap 4 in that it has a reduced top surface area 65. Hence, if the same pressure is applied to the end surface 65 as is applied to the end of the caps 4 in the plugs 20, 40 then the total force applied to the surface 65 of the end cap 64 will be less due to the reduced surface area. This makes the plug 60 ideal for use in positive pressure situations, that is in situations where it is desirable to maintain a higher pressure in the well above the plug 60 and below the plug 60.

Claims: A downhole tool for use in an oil or gas well; the tool having a main body (1), and a flow channel (16) in the main body (1) which is initially closed by a valve member (4); the valve member (4) being openable by a mechanism which comprises a locking member (10) initially in a first position in which the valve member (4) is held closed, a reciprocable piston member (6) acted upon by well fluid pressure and biased against well fluid pressure, and unidirectional drive means (8, 11, 12) coupled to the piston member (6) and the locking member (10), such that repeated reciprocation of the piston member (6) by repeated application of well fluid pressure moves the unidirectional drive means to a release position in which the locking member (10) and the valve member (4) may be moved to open the flow channel (16); characterised in that: the tool (20) is a plug for closing a bore (30) through a lock (23) engaged and sealed in a landing nipple (24a); the flow channel (16) in the tool, in use, connects the lock bore (30) to the well below the plug; the unidirectional drive means (8, 11, 12) acts between the piston member (6) and the locking member (10) and comprises a catch (11) which holds the locking member (10) in said first position until the piston member (6) has undergone a number of reciprocations to cause the catch (11) to move to the release position in which the locking member (10) is free to move out of engagement with a formation (17) on the inner wall of the main body (1) to allow sliding movement of an intermediate member (5) with respect to the main body (1), which sliding movement in turn permits movement of the valve member (4) past the flow channel (16); the piston member (6) comprises an elongate member having an end face (33) exposed to well pressure in the lock bore (30); and the valve member (4) encircles the piston member (6) and has an end face which is exposed to well pressure in the lock bore (30). A tool according to Claim 1, in which the piston member (6) is arranged axially and the valve member (14) is concentric therewith. A tool according to Claim 1 or Claim 2, wherein the unidirectional drive means comprises a first ratchet mechanism (8, 18) acting between the piston member (6) and the catch (11) and a second ratchet mechanism (12, 22) acting between the catch (11) and a stationary part (13) of the tool. A tool according to Claim 3, wherein one ratchet mechanism (8, 18) permits movement in a first direction and grips in a second direction and the other ratchet mechanism (12, 22) grips in the first direction and permits movement in the second direction. A tool according to any preceding claim, wherein the piston member (6) is biased against well fluid pressure by spring means (7). A tool according to any preceding claim, including valve spring means (42) exerting a biasing force urging the valve member (4) towards its open position.

Inventors: REID MICHAEL ADAM, REID, MICHAEL ADAM
Applicants: WELL EQUIP LTD, WELL-EQUIP LIMITED
Application year: 1991
Main classification: E21B23
IPC codes: E21B34, E21B33, E21B23