Well tool device and shatter valve device with actuation system
Patent Information
- Application Number
- AE202602574
- Authority / Receiving Office
- AE · AE
- Patent Type
- Applications
- Current Assignee / Owner
- Priority Date
- 2024-02-02
- Filing Date
- 2025-01-31
Smart Images
Figure ABST_ABST
Abstract
Description
Well tool device and shatter valve device with actuation systemTechnical FieldThe present invention relates to a well tool device for a well. The present invention also relates to a shatter valve device. BackgroundNO 343864 and NO 343059 describes a well tool which is integrated in a lower end of a production tubing (also referred to as a completion string). The tool has a housing having a longitudinal through bore, in which a sleeve is longitudinally displaceable relative to the housing. A frangible disc is secured inside the sleeve. The tool has three states:1: an initial state, in which fluid is allowed to bypass the frangible disc. In this state, fluid is allowed to enter the production tubing as the production tubing is lowered into the well. 2: a closed state, in which pressure can be increased above and / or below the frangible disc for pressure testing purposes.3: a final state, in which the frangible disc has been disintegrated, allowing fluid to flow through the tool, typically during the production phase of the well. The Interwell IRBV tool is based on the technology of the two above publications. The Interwell IRBV tool has a first actuation system for bringing the tool from the initial state to the closed state and a second actuation system for bringing the tool from the closed state to the final state. NO 328882 describes a previous actuation system for bringing the Interwell IRBV tool from the closed state to the final state. The actuation system comprises an annular sleeve provided with non-through-going recesses in the material of the annular sleeve, where separate replaceable elements are provided in the recesses to act as a pump, piston, reservoirs, movable slide and pistons, where these elements create a closed fluid circuit which on being subjected to a number of cyclical loads will open up a connection between the pistons. Another tool, the Interwell IRSV tool is similar to the Interwell IRBV tool. However, the Interwell IRSV tool has only two states, an initial closed state and an final open state. The second actuation system of the Interwell IRBV tool can be found in the Interwell IRSV tool for bringing the tool from the closed state to the open state. In some applications, it is desirable to let the tool stay in the closed state as a barrier for a longer period of time. In such an application, it is important that the actuation system which are used to bring the above tools from their closed state to their open state is not accidentally triggered to open the barrier.One object of the present invention is to improve the above prior art tool. In particular, one object is to provide a fail-safe mechanism in order to reduce or at least considerably reduce the risk for accidental triggering the actuation system which are used to bring the above tools from their closed state to their open state. Summary of the inventionThe present invention relates to a well tool device for a well, wherein the well tool device comprises: - an outer housing; - an inner housing provided radially inside the outer housing, wherein the inner housing comprises a longitudinal through bore; - an actuation system for operating the well tool device between a plurality of operational states, wherein the plurality of operational states comprise an initial state, a first unlocked state, a second unlocked state, and a final state;wherein the actuation system comprises a first locking mechanism, the first locking mechanism including a first actuator that is locked in the initial state and unlocked in the first unlocked state, the second unlocked state, and the final state, wherein well tool device is configured to be brought from the initial state to the first unlocked state by applying a first predefined fluid pressure within the bore;wherein the actuation system comprises a second locking mechanism, the second locking mechanism including a second actuator that is locked in the initial state and the first unlocked state and that is unlocked in the second unlocked state and the final state, and wherein the well tool device is configured to be brought from the first unlocked state to the second unlocked state by applying a second predefined fluid pressure within the bore to cause the first actuator to move into engagement with the second locking mechanism; and wherein the well tool device is configured to be brought from the second unlocked state to the final state by applying a third predefined fluid pressure within the bore to cause the second actuator to move relative to the inner housing.The first, second and / or third predefined fluid pressures within the bore may be predefined changes in fluid pressure. The first, second and / or third predefined fluid pressures within the bore may be a predefined number of changes in fluid pressure.The first, second and / or third predefined fluid pressures within in the bore may be triggered by an operator located topside. The operator may be a person operating a fluid pump. The operator may be an automatically controlled fluid pump.The initial state may be referred to as an unactuated state. The final state may be referred to as an actuated state. The first unlocked state and the second unlocked state may be referred to as intermediate states between the initial state and the final state.According to the above, it is achieved a well tool device with two locking mechanisms, where the first locking mechanism unlocks the second locking mechanism, and where both locking must be unlocked in order to reach the final state. If the first locking mechanism fails, it is not possible to reach the final state. If the second locking mechanism fails, it is not possible to reach the final state.The actuation system may be used for a number of purposes. The purpose may be to bring a valve of the well tool device from an initial closed state to a final open state or from an initial open state to a final closed state. The valve may be a ball valve, where the movement of the second actuator relative to the inner housing is rotating the ball valve from a closed state to an open state or vice versa.The valve may be a sleeve valve where the movement of the second actuator relative to the inner housing is moving the sleeve between a position where the sleeve is allowing fluid flow to a position where the sleeve is preventing fluid flow or vice versa.The valve may be a glass disc where the movement of the second actuator relative to the inner housing is moving the glass disc from a position where the glass disc is preventing fluid flow to a position where the glass disc is disintegrated and thereby allows fluid flow. The glass disc may be moved to a position where the glass disc becomes into contact with knives or other types of disintegration devices which disintegrates the glass.The purpose may be to trig or initiate further states of the well tool device. The further state may be a radially retracted state, where a radially expanded part of the well tool device becomes radially retracted, or a radially expanded state, where a radially retracted part of the well tool device becomes radially expanded. The part may be a perforator, a sealing element, an anchoring element etc. The energy needed to move the part may be the fluid pressure of the bore and / or the fluid flow through the bore. The energy needed to move the part may be stored in an energy storing device. The movement of the second actuator relative to the inner housing may be used to release the energy stored in the energy storing device. The energy storing device may be a chemical storing device or a mechanical storing device. The chemical storing device may be an explosive material, a battery etc. The mechanical storing device may be a spring.The second actuator may comprise an actuator sleeve, and wherein the second locking mechanism may comprise a locking segment provided radially outside of at least parts of the actuator sleeve and radially outside of at least parts of the inner housing, wherein the locking segment may be preventing movement of the actuator sleeve relative to the inner housing in the initial state and wherein the locking segment may be allowing movement of the actuator sleeve relative to the inner housing in the second unlocked state and in the final state.The locking segment may be integrated with or provided as part of the inner housing. The locking segment may be integrated with or provided as part of the actuator sleeve. The locking segment may be a part separate from both the inner housing and the actuator sleeve.The locking segment may comprise one single segment. The locking segment may be referred to as a locking ring. The locking segment may comprise a number of segments. The number of segments together may be referred to as a locking ring.The second actuator may comprise a longitudinal through bore, wherein the longitudinal through bore is axially aligned with the bore of the inner housing.The actuator sleeve may be located at least partially radially inside the inner housing. The actuator sleeve may be located at least partially longitudinally below or longitudinally above the inner housing. The actuator sleeve may be sealingly engaged with the inner housing in the initial state in the first unlocked state and in the second unlocked state. The actuator sleeve may be moved out of sealing engagement with the inner housing in the final state.The second predefined fluid pressure within the bore may be causing the first actuator to move in a longitudinal direction into engagement with the locking segment of the second locking mechanism.The movement of the first actuator may be rotating the locking segment.The locking segment may be rotated relative to the inner housing. The locking segment may be rotated relative to the actuator sleeve. The locking segment may be rotated relative to both the inner housing and the actuator sleeve.The longitudinal direction may be parallel with a longitudinal center axis of the well tool device. The locking segment may be rotated around the longitudinal center axis of the well tool device.The locking segment may comprise an inclining surface that the first actuator engages upon movement of the first actuator and / or wherein a locking segment facing end of the first actuator may comprise an inclining surface configured to engage the locking segment, in order to rotate the locking segment by movement of the first actuator.The inclining surface may have an angle of 15° - 60°, preferably ca 30° with respect to the direction in which the first actuator is moved.The second actuator may comprise radially protruding locking elements on an outer surface thereof and wherein the inner housing may comprise radially protruding locking elements on an outer surface thereof, and wherein the locking segment may comprise complementary grooves on an inner radial surface thereof for preventing relative movement between the locking elements of the second actuator and the locking elements of the inner housing in the initial state and in the first unlocked state.The locking segment may be allowing relative longitudinal movement between the locking elements of the second actuator and the locking elements of the inner housing in the second unlocked state and in the final state.The well tool device may comprise a first chamber which may be closed in the initial state and in the first unlocked state and which may be open in the second unlocked state and the final state, wherein the locking segment may be provided within the first chamber.The first chamber may be closed topside, before lowering the well tool device into the well. Hence, the first chamber may have atmospheric pressure in the initial state and in the first unlocked state.Hence, at least in the initial state and in the first unlocked state, the locking segment is unaffected by the fluid pressure within the bore. Hence, it is relatively easy to rotate the locking segment relative to the inner housing and / or the actuator sleeve.The second actuator may comprise a piston surface on the outside of the actuator sleeve; and wherein the well tool device may comprise a second chamber which may be closed in the initial state, in the first unlocked state and in the second unlocked state, wherein the piston surface may be located within the second chamber.The second chamber may be closed topside, before lowering the well tool device into the well. Hence, the second chamber may have atmospheric pressure in the initial state, in the first unlocked state and in the second unlocked state.As the piston surface is provided within the second chamber having atmospheric pressure, it is considered relatively easy to initiate the movement of the second actuator relative to the inner housing.The inner housing may be provided above the actuator sleeve. The first chamber may be provided above the second chamber. The piston surface may be facing downwardly.The second locking mechanism may comprise a rotation preventing lock for preventing unintentional rotation of the locking segment relative to the actuator sleeve and / or relative to the inner housing in the initial state and in the first unlocked state.The rotation preventing lock may comprise a spring-biased ball segment received within a ball receiving recess of the locking segment.The first locking mechanism may comprise one or, or several of, the following: - a liquid-filled compartment provided at least partially within the inner housing;- a piston sleeve defining a first longitudinal end of the liquid-filled compartment; - a first fluid line defining a second longitudinal end of the liquid-filled compartment; - a pressure counter for counting a predetermined number of pressure increases and pressure decreases in the bore representing the first predefined fluid pressure;- a locking element releasably connected between the first actuator and the inner housing; wherein the locking element may be preventing relative movement between the first actuator and the inner housing in the initial state and wherein the pressure counter may be configured to release the locking element in order to allow relative movement between the first actuator and the inner housing in the first unlocked state; wherein the pressure counter and the locking element may be located within the liquid-filled compartment.The locking element may be releasably connected between the first actuator and the inner housing via the pressure counter.The first actuator may be provided in sealing engagement within the fluid line in the initial state and in the first unlocked state and wherein the first actuator may be brought out of its sealing engagement within the fluid line in the second unlocked state and in the final state.The first actuator may be brought out of its sealing engagement within the fluid line by means of the second predetermined pressure in the bore.The first chamber may be located adjacent to the liquid-filled compartment. The first fluid line may be providing fluid communication between the liquid-filled compartment and the first chamber. The first actuator may be preventing such fluid communication in the initial state and in the first unlocked state. The fluid of the liquid-filled compartment may be allowed to flow into the first chamber when the first actuator is brought out of sealing engagement with the fluid line.The liquid-filled compartment may be filled with glycol or a similar fluid.The first actuator may be brought out of sealing engagement with the fluid line in the second unlocked state and in the final state due to a pressure difference between the fluid in the bore and the fluid within the first chamber.The second predetermined pressure in the bore may be the pressure difference between the fluid in the bore and the fluid within the first chamber.The piston sleeve may be provided radially outside of the inner housing and radially inside of the outer housing. The piston sleeve may be longitudinally movable relative to the inner housing and relative to the outer housing. The piston sleeve may be sealingly engaged with the inner surface of the outer housing and may be sealingly engaged with the outer surface of the inner housing. The fluid pressure of the bore may affect the upwardly facing surface of the piston sleeve.The inner housing may comprise a second fluid line, wherein the second fluid line may be defining the second longitudinal end of the liquid-filled compartment together with the first fluid line; wherein the pressure counter comprises: - a spring-biased sleeve affected by the pressure in the bore; - springs biasing the spring-biased sleeve relative to the inner housing; - a chamber rod sealingly engaged in the second fluid line, wherein a first end of the chamber rod may be connected to the spring-biased sleeve.Hence, when the pressure in the bore becomes sufficiently high, the springs will be compressed and the spring-biased sleeve will move longitudinally towards the first fluid line and towards the second fluid line. In the initial state and in the first unlocked state, the first actuator is locked and will not move even if the spring-biased sleeve moves. However, the chamber rod will move together with the spring-biased sleeve and compress / decompress the gas in the first chamber based on the reciprocating movement of the spring-biased sleeve. When the pressure in the bore becomes reduced again, the springs will push the spring-biased sleeve back to its original position.The spring-biased sleeve may be affected by the pressure in the bore directly. The spring-biased sleeve may be affected by the pressure in the bore via the piston sleeve.The pressure counter comprises: - a first ratchet element having a first end connected to the spring-biased sleeve; - a second ratchet element engaged with the first ratchet element, wherein movement of the first ratchet element relative to the second ratchet element in a first direction may be allowed and wherein movement of the first ratchet element relative to the second ratchet element in a second direction opposite of the first direction causes the second ratchet element to move together with the first ratchet element, wherein the second ratchet element may be in a position in which the locking element is supported in order to maintain the first actuator locked in the initial state and wherein the second ratchet element may be moved to a position in which the locking element is not supported in the first unlocked state.The first end of the first ratchet element may be connected to the spring-biased sleeve via a clutching system allowing the spring-biased sleeve to move a longitudinal distance being longer than a maximal allowed longitudinal distance for the first ratchet element to move.In an alternative embodiment, the pressure counter is an electronic pressure counter and the locking element is an electric actuator, wherein the pressure counter is configured to send an electric signal to the locking element after counting a predetermined number of pressure cycles.According to the above, should a fluid leakage cause the pressure in the liquid-filled compartment to be equal to the pressure within the first chamber in the initial state or in the first unlocked state, movement of the first actuator is prevented. Hence, it will not be possible to bring the well tool device to the second unlocked state and / or to the final state. If the well tool device has a valve being closed in the initial state, the well tool device will not open if such a leakage has occurred. Hence, the valve defaults to a closed position, which is typically desired in many well applications.The first predefined fluid pressure may be a predetermined number of pressure increases and pressure decreases in the bore sufficient to actuate a pressure counter in order to unlock the first locking mechanism. The second predefined fluid pressure may be a pressure in the bore being sufficient to move the first actuator longitudinally into engagement with the locking segment and to rotate the locking segment, i.e. to unlock the second locking mechanism. The third predefined fluid pressure may be a pressure in the bore being sufficient to move the second actuator longitudinally relative to the inner housing.The present invention relates to a shatter valve device, wherein the shatter valve device comprises:- a well tool device according to any one of the above claims; - a plug device defined with a closed state and a final open state; wherein the plug device comprises:- an outer housing connected to or being a part of the outer housing of the well tool device; - a sleeve section provided radially inside the outer housing below or above the inner housing; wherein the sleeve section comprises a through bore aligned with the bore of the inner housing; - a frangible glass body sealingly engaged within the bore of the sleeve section in the closed state;- a disintegration device seated within the sleeve section;wherein in the final state, the third predefined fluid pressure within the bore and the the movement of the second actuator relative to the inner housing are causing the frangible glass body to move into contact with the disintegration device and disintegrate the frangible glass body, thereby bringing the plug device to the final open state.The plug device may prevent longitudinal fluid flow through the sleeve section and hence also prevent longitudinal fluid flow through the bore of the inner housing in the closed state. The plug device is in the closed state when the well tool device is in the initial state, the first unlocked state and the second unlocked state.The plug device may allow longitudinal fluid flow through the sleeve section and hence also allowing longitudinal fluid flow through the bore of the inner housing in the final open state. The plug device is in the final open state when the well tool device is in the final state.The plug device may comprise a retaining sleeve for retaining the frangible glass body within the sleeve section, wherein the retaining sleeve may be moved longitudinally away from the frangible glass body by the movement of the second actuator, thereby allowing the frangible glass body to move into contact with the disintegration device.The plug device may comprise an actuation rod mechanically connecting the second actuator to the retaining sleeve.Unintentional movement of the retaining sleeve may be provided by connecting the retaining sleeve to the sleeve section or other parts of the plug device by means of a shear element. Unintentional movement of the retaining sleeve may be achieved by connecting the actuation rod to the sleeve section by means of a shear element or to other parts of the plug device.The sleeve section may be longitudinally displaceable within the outer housing and may comprise a first opening above the frangible glass body and a second opening below the frangible glass body and wherein the outer housing of the plug device may comprise a longitudinal bypass fluid line; wherein the plug device may be defined with an initial open state; wherein, in the initial open state, longitudinal fluid flow may be allowed between the bore above the frangible glass body and the bore below the frangible glass body via the first opening, the second opening and the bypass fluid line; wherein the plug device may comprise a further actuation system for moving the sleeve section to a position in which longitudinal fluid flow through the first opening, the second opening and bypass fluid line is closed.As used herein, the term “atmospheric pressure” is used herein to denote a pressure being much lower than the pressure in the well in which the well tool device is being used. Typically, “atmospheric pressure” is achieved by closing a volume of the well tool device topside, either as part of manufacturing or as part of preparations for the well operation in which the well tool device is being used. It is well known that the atmospheric pressure typically varies dependent on the height above sea level, where the atmospheric pressure is 1 bar at sea level. When the well tool is lowered into an oil and / or gas well, the fluid pressure in the well will be substantially higher than the pressure in the tank. Hence, variations in the so-called atmospheric pressure is neglectable with respect to the fluid pressure in the well. It should be noted that the term “atmospheric pressure” may here also refer to a pressurized volume of the well tool device, as long as pressure in the pressurized volume is neglectable with respect to the fluid pressure in the well.The terms “upper”, “above”, “below” and “lower” are used herein to define parts of the well tool device, when the well tool device is used in a well. “Upper” and “above” refer to a position relatively closer to the well opening and “below“ and “lower” refer to a position relatively further away from the well opening. These terms apply both when the well has a vertical and horizontal orientation.Similarly, the terms “outside” and “inside” are used herein to refer to relative radial locations, the radial direction being perpendicular to a longitudinal axis of the well and hence also the longitudinal axis of the well tool device.As used herein, the terms “radially retracted state” and “run state” are used interchangeably for the state in which the well tool is lowered to a desired location in the well. The terms “radially expanded state” and “set state” are used interchangeably for the state in which the well tool is engaged with the inner surface of the well at the desired location in the well. List of drawingsFig. 1 is a perspective view of a section of a well tool device in the initial state, where a part of the outer housing has been removed; Fig. 2 is a side view of the section of the well tool device in the initial state, where the outer housing and some other parts have been removed; Fig. 3 is an enlarged view of detail A in fig. 2; Fig. 4a is a perspective view of the well tool device in the initial state, where the entire outer housing has been removed; Fig. 4b is an enlarged view of detail C in fig. 4a, where a part of the locking segment has been removed; Fig. 5 corresponds to fig. 1, but in the final state; Fig. 6 corresponds to fig. 2, but in the final state; Fig. 7 is an enlarged view of detail I in fig. 6; Fig. 8a corresponds to fig. 4a; Fig. 8b is an enlarged view of detail K in fig. 8a, where a part of the locking segment has been removed; ; Fig. 9a corresponds to fig. 4a, but from a different angle;Fig. 9b shows detail G of fig. 9a; Fig. 10 shows the well tool device in the form of a shatter valve device.Detailed descriptionWell tool device 1 with actuation system 10Initially, it is referred to fig. 1, where a well tool device 1 is shown. The well tool device 1 comprises a substantially cylindrical outer housing 2 with a through bore defined by an inner surface 2s. The inner surface 2s comprises several recesses (for example 2r31a, 2r31b) for sealing elements (not shown in fig. 1) in the form of O-rings etc. These will be described further in detail below. In general, the drawings show recesses meant for sealing elements in the form of O-rings. It should be noted that at least some of these O-rings have been removed from the drawings. In fig. 1, a longitudinal centre axis LCA is indicated for the well tool device 1. It should be noted that the well tool device 1 typically will be a part of a larger well tool. Examples of such a larger well tool will be described further in detail below. As an example, the outer housing 2 may comprise an upper connection interface (not shown) and a lower connection interface (not shown) for connection to a completion string. The orientation of the well tool device 1 in the drawings corresponds to the orientation of the well tool device in a well, i.e. the lower part of the well tool device 1 in the drawings are facing towards the lower end of the well and the upper part of the well tool device 1 in the drawings are facing towards the topside of the well. The well tool device 1 further comprises an inner housing 20 provided radially inside the outer housing 2. The inner housing 20 comprises a longitudinal through bore 21 through which a fluid may flow through the well tool device 1. The inner housing 20 comprises an upper neck section 20n, a main section 20m and a lower section 20l, where the upper neck section has an outer diameter being smaller than an outer diameter of the main section 20m. The well tool device 1 further comprises an actuation system 10 for operating the well tool device 1 between a plurality of operational states, wherein the plurality of operational states comprise an initial state S0, a first unlocked state S1, a second unlocked state S2, and a final state S3. This actuation system 10 comprises a first locking mechanism 30 including a first actuator 38 and a second locking mechanism 40 including a second actuator 48. Below, primarily the initial state S0 of the actuation system 10 will be described more in detail, and then, the operation of the actuation system 10 and its subsequent states will be described. The first locking mechanism 30 It is now referred to fig. 1, fig. 2 and fig. 3. Here it is shown that the first locking mechanism 30 comprises a liquid-filled compartment 31 provided at least partially within the inner housing 20. In fig. 1, the longitudinal extent of the liquid-filled compartment 31 is indicated between recesses 2r31a, 2r31b of the outer housing 2. The first locking mechanism 30 comprises a piston sleeve 33 provided radially outside of the upper neck section 20n of the inner housing 20. The piston sleeve 33 is sealingly engaged with both the upper neck section 20n and the outer housing 2, and forms a piston which may move longitudinally relative to the inner housing 20 (see also recesses 33r and 2r31a of fig. 10). The upper side of the piston sleeve 33 is exposed to the fluid pressure of the bore 21, while the lower side of the piston sleeve 33 is exposed to the pressure within the liquid-filled compartment 31. The first locking mechanism 30 further comprises a first fluid line 32 in which the first actuator 38 is sealingly engaged. The first fluid line 32 is here a cylindrical bore, and the first actuator 38 is a cylindrical rod, where sealing elements 38s are provided radially outside of this cylindrical rod. The first fluid line 32 has an first section 32a and a second section 32b, where the diameter of the first section 32a is smaller than the second section 32b. In fig. 3, it is further shown that the lower end of the first actuator comprises an inclining surface 38is having an angle α of ca 30° relative to the longitudinal direction.It is now referred to fig. 9a. Here it is shown that the inner housing 20 further comprises a second fluid line 29 extending longitudinally through the main section 20m of the inner housing 20 (the entire length of the second fluid line 29 is not shown in fig. 9a, here only a part of the inner housing 20 has been removed to show parts of the second fluid line 29. A chamber rod 34rod is sealingly engaged in the second fluid line 29 by means of sealing elements 34rods. The piston sleeve 33 forms a first or upper longitudinal end of the liquid-filled compartment 31. The first fluid line 32, the second fluid line 29, the sealing elements 38s, 34rods together with the recess 2r31b form a second or lower end of the liquid-filled compartment 31. The first locking mechanism 30 further comprises a pressure counter generally indicated by reference number 34 in fig. 3. The pressure counter 34 comprises several parts provided within the liquid-filled compartment 31:- a spring-biased sleeve 34s provided at a distance below the piston sleeve 33;- springs 34sp biasing the spring-biased sleeve 34s relative to the main section 20m of the inner housing 20; - a first ratchet element 34r1 having a first end connected to the spring-biased sleeve 34s via a clutching system 34r, 34c; and - a second ratchet element 34r2 engaged with the first ratchet element 34r1. A first end of the chamber rod 34rod is connected to the spring-biased sleeve 34s. Hence, as will be described further in detail below, when the spring-biased sleeve 34s moves longitudinally up / down, then also the chamber rod 34rod moves up / down within the second fluid line 29 accordingly. The first ratchet element 34r1 is engaged with the second ratchet element 34r2. Movement of the first ratchet element 34r1 relative to the second ratchet element 34r2 in a first downward direction D34A is allowed, while movement of the first ratchet element 34r1 relative to the second ratchet element 34r2 in a second upward direction D34B opposite of the first direction D34A causes the second ratchet element 34r2 to move together with the first ratchet element 34r1. Hence, the first ratchet element 34r1 moves up and down when the spring-biased sleeve 34s moves up and down, while the second ratchet element 34r2 only moves up. The longitudinal movement of the first ratchet element 34r1 is limited by a movement restricting system. As shown in fig. 3, the first ratchet element 34r1 has two spaced apart teeth 34t1, 34t2 protruding in a direction perpendicular to the directions D34A, D34B, and the housing 20 has a tooth 24 protruding into the space between the teeth 34t1, 34t2. When the first ratchet element 34r1 is in its upper position shown in fig. 3, the lower tooth 34t2 is engaging the tooth 24. The first ratchet element 34r1 may move down until the upper tooth 34t1 becomes engaged with the tooth 24. The distance D34r1 is representing the maximum longitudinal movement of the first ratchet element 34r1 between the two spaced apart teeth 34t1, 34t2. The clutching system 34r, 34c comprises a clutch rod 34r having a first end connected to the spring-biased sleeve 34s and a second end connected to a clutch 34c. The clutch 34c is again connected to the upper end of the first ratchet element 34r1. As indicated in fig. 3, a distance D36s representing the maximum longitudinal movement of the spring-biased sleeve 34s is larger than the distance D34r1 representing the maximum longitudinal movement of the first ratchet element 34r1. Initially, when the force from the fluid pressure in the bore 21 becomes larger than the force from the springs 34sp, the spring-biased sleeve 34s will start to move downwardly. The clutching system will push the first ratchet element 34r1 downwardly until it has moved the maximum travel distance determined by the movement restricting system. The clutching system will allow the spring-biased sleeve 34s to move further down, without moving the first ratchet element 34r1. The first locking system 30 further comprises a locking element 35 releasably connected between the first actuator 38 and the main section 20m of the inner housing 20. The locking element 35 is maintained in its position shown in fig. 3 by means of the second ratchet element 34r2. One advantage with the movement restricting system is that the pressure counter 34 can be used for a larger variation of expected well pressures, without having to change the number of and / or the properties of the springs 34sp. As an example, if the first locking system 30 were used at a location having a relative low pressure, the spring-biased sleeve 34s will move a distance being relatively shorter than if the same first locking system 30 were used at another location with a relatively higher pressure. This could cause the first ratchet element 34r1 to move longer at a high pressure location than at a low pressure location, and hence fewer pressure cycles would be needed to release the locking element 35 at a high pressure location than at a low pressure location. This is normally not accepted, since the operation require certainty with respect to the number of pressure cycles needed to release the locking element 35. One way of solving this would be to change the number of and / or the properties of the springs 34sp based on the expected well pressure at the location in which the well tool device 1 is to be used. This is cumbersome and reduces flexibility during manufacturing and storage. In the present embodiment, the second ratchet element 34r2 will move the same distance in a well with a relatively high pressure as in a well with a relatively low pressure due to the two spaced apart teeth 34t1, 34t2 and the tooth 24. In the present embodiment, the liquid-filled compartment 31 is filled with glycol. In the present embodiment, the actuation system 10 comprises two first locking systems 30, the first one being on the opposite side of the second one (as indicated in fig. 10, here two first actuators 38 are indicated). The second locking mechanism 40It is now referred to fig. 1, fig. 2 and fig. 3. Here it is shown that the second actuator 48 comprises an actuator sleeve 48s and a longitudinal through bore 48b through the actuator sleeve 48s. The actuator sleeve 48s is provided radially inside of the outer housing 2 and longitudinally at least partially below the inner housing 20. In fig. 10, an overlapping region OR is indicating a region where an upper end of the actuator sleeve 48s is provided radially inside of a lower end of the inner housing 20. The The longitudinal through bore 48b is axially aligned with the bore 21 of the inner housing 20. Hence, the bore 21 together with the bore 48b forms one single bore through which fluid may flow through the well tool device 1. The actuator sleeve 48s is sealingly engaged with the inner housing 20, as indicated by means of recess 48rs in fig. 10. The second actuator 48 further comprises a piston surface 48ps on the outside of the actuator sleeve 48s. The piston surface 48ps is formed by the transition area between a lower section of the actuator sleeve 48s having an outer diameter being smaller than an outer diameter of an upper section of the actuator sleeve 48s. It is now referred to fig. 4b. Here it is shown that the second actuator 48 comprises radially protruding locking elements 48a distributed circumferentially around an outer surface of the upper end of the actuator sleeve 48s. Similarly, the inner housing 20 comprises radially protruding locking elements 28a distributed circumferentially around an outer surface of the lower section 20l of the inner housing 20. As shown in fig. 4b, the locking elements 48a, 28a are longitudinally aligned with each other. The second locking mechanism 40 further comprises a locking segment 43 provided radially outside of the locking elements 48a of the actuator sleeve 48s and radially outside of the locking elements 28a of the inner housing 20. The locking segment 43 comprises grooves 43a on an inner radial surface thereof. These grooves serves two purposes:- the grooves 43a prevents relative movement between the locking elements 48a of the second actuator 48 and the locking elements 28a of the inner housing 20 when the locking segment 43 is in a first position, and- the grooves 43a allows relative movement between the locking elements 48a of the second actuator 48 and the locking elements 28a of the inner housing 20 when the locking segment 43 is in a second position. In fig. 4b, a part of the locking segment 43 has been removed to show the locking elements 28a, 48a and groove 43a. In addition, the locking segment 43 comprises an inclining surface 43is adapted to be engaged by the inclining surface 38is of the first actuator 38. The inclining surface 43is preferably has an angle similar to or identical to the angle α of the inclining surface 38is of the first actuator 38. In the present embodiment, there are two locking segments 43, each having a shape resembling a hollow cylinder cut in two along a longitudinal plane. It is now referred to fig. 1 again. Here it is shown that the well tool device 1 comprises a first chamber AC1 located below the liquid-filled compartment 31. The first chamber AC1 is extending from a location above the locking segment 43, as indicated by recess 2rAC1a, and to a location below the locking segment 43, as indicated by recess 2rAC1b. Hence, the locking segment 43 is provided within the first chamber AC1. The first chamber AC1 is filled with a gas with atmospheric pressure. The first fluid line 32 and the second fluid line 29 are both extending into the first chamber AC1. However, as described above, as the first actuator 38 is sealingly engaged within the first fluid line 32 and as the chamber rod 34rod is sealingly engaged within the second fluid line 29, the liquid within the liquid-filled compartment 31 will not flow into the first chamber AC1. It should further be noted that the first chamber AC1 is separated from the bore 21 and the bore 48b. In fig. 1 it is further shown that the well tool device 1 comprises a second chamber AC2 located below first chamber AC1. The second chamber AC2 is extending from a location above the piston surface 48ps, as indicated by recess 2rAC2a (in the present embodiment being identical to the recess 2rAC1b), and to a location below the piston surface 48ps, as indicated by recess 2rAC2b. Hence, the piston surface 48ps is provided within the second chamber AC2. The second chamber AC2 is filled with a gas with atmospheric pressure. It should further be noted that the also the second chamber AC2 is separated from the bore 21 and the bore 48b.It is now referred to fig. 9b. Here it is shown that the second locking mechanism 40 further comprises a rotation preventing lock 47 for preventing unintentional rotation of the locking segment 43 relative to the actuator sleeve 48s and relative to the inner housing 20. In theory, such unintentional rotation could take place, for example due to vibrations etc. The rotation preventing lock 47 here comprise a spring-biased ball segment 47bs received within a ball receiving recess 43br of the locking segment 43. Operation of the actuation system 10The operation of the well tool device 1 and in particular the operation of the actuation system 10 will be described in detail. The initial state S0 has been described above. In this state, the well tool device 1 may be lowered into the well to its desired location. Due to the rotation preventing lock 47, the locking segment 43 will not be able to rotate relative to the inner housing 20 or rotate relative to the actuator sleeve 48s. The well tool device 1 may be situated in the well for a long period of time, in some situations up to several months or even years. When it is desired to actuate the actuation system 10, a number of pressure cycles within the bore 21 is applied by means of a topside pump. The pressure is increased to a pressure causing the piston sleeve 33 and the spring-biased sleeve 34s to move downwardly. It should be noted that the liquid-filled compartment 31 is closed, and that the liquid is considered incompressible. It should further be noted that there is a distance between the piston sleeve 33 and the spring-biased sleeve 34s. Hence, as piston sleeve 33 is pushed down, it pushes the liquid below the piston sleeve 33 down, which again pushes the spring-biased sleeve 34s down.The chamber rod 34rod connected to the spring-biased sleeve 34s will now move down within the second fluid line 29 and compress the gas within the first chamber AC1. It should be noted that the first actuator 38 will not move, since the locking element 35 is preventing any movement of the first actuator 38. Together with the spring-biased sleeve 34s also the first ratchet element 24r1 will move down relative to the second ratchet element 24r2. The pressure is now decreased to a pressure causing the piston sleeve 33 and the spring-biased sleeve 34s to move upwardly. The second ratchet element 24r2 will now move upwardly together with the first ratchet element 24r1. The pressure is then increased and decreased again, repeating the above until the second ratchet element 24r2 is no longer supporting the locking element 35. It is now referred to fig. 6 and 7. Here it is shown that the locking element 35 has fallen down and out of engagement with the first actuator 38. This is referred to as a first unlocked state S1, where the first actuator 38, and hence the first locking mechanism 30, has been unlocked and the first actuator 38 is free to move within the first fluid line32 relative to the inner housing 20. In fig. 2 and fig. 3, a distance D38 is indicating the distance between the lower end of the first actuator 38 and the transition area between the first section 32a and the second section 32b of the first fluid line 32. The fluid pressure in the bore 21 is here sufficient to or will be increased to a pressure sufficient to cause the piston sleeve 33 to move down. This will increase the pressure within the liquid-filled compartment 31. Now, this increased pressure will cause the first actuator 38 to move down in a longitudinal direction (indicated by arrow A38) as shown in fig. 8b. The pressure difference over the first actuator 38 is represented by the fluid pressure in the bore 21 which is much smaller than the gas pressure within the first chamber AC1. This pressure difference will move the first actuator 38 before it will be able to counteract the springs 34sp and hence move the spring-biased sleeve 34s. Due to the inclining surfaces 38is, 43is, this longitudinal direction A38 will rotate the locking segment 43 (indicated by arrow A43). The rotation of the locking segment 43 will bring the locking segment 43 from the first position to the second position, the second position being a position in which the grooves 43a allows relative movement between the locking elements 48a of the second actuator 48 and the locking elements 28a of the inner housing 20. This is referred to as a second unlocked state S2 where the actuator sleeve 48s, and hence the second locking mechanism 40, has been unlocked and the actuator sleeve 48s is free to move relative to the inner housing 20.Referring back to fig. 6 and 7 again, it is here shown that the distance D38 is longer than the distance D38 of fig. 2 and 3. In fig. 7 it is also shown that the recesses 38 for the sealing elements around the first actuator 38 have been moved from a position within the first section 32a to a position within the second section 32b of the first fluid line 32. As this second section 32b has a larger inner diameter, the first actuator 38 is no longer sealingly engaged in the first fluid line 32 and the liquid in the liquid-filled compartment 31 will flow into the first chamber AC1. In the initial state S0, the volume of liquid in the annular compartment between the piston sleeve 33 and the spring-biased sleeve 34s is larger than the volume of the first chamber AC1. Hence, liquid will fill the first chamber AC1 as the piston sleeve 33 moves towards the spring-biased sleeve 34s. This liquid will now push the second actuator 48 (i.e. the actuator sleeve 48s) in the longitudinal direction indicated by arrow A48, i.e. away from the inner housing 20 (see fig. 8b). The movement of the second actuator 48 is here helped by the piston surface 48ps of the actuator sleeve 48s being located in the second chamber AC2, which still have a relatively low pressure. As shown in fig. 3, a distance D48 between the locking elements 28a and the locking elements 48a is zero. In fig. 7, this distance D48 has increased. This is referred to as a final state S3 where the second actuator 48, and hence the actuator sleeve 48s, has moved longitudinally relative to the inner housing 20.In the present embodiment, the actuator sleeve 48s will move out of sealing engagement with the inner housing 20 when the actuator sleeve 48s has moved approximately past the overlapping region OR, i.e. when the upper end of the actuator sleeve 48s (fig. 10) has moved below the sealing element in the recess 48rs. When this happens, the fluid pressure within the bore 21 will affect the actuator sleeve 48s directly. It should be noted that the downwardly directed movement of the actuator sleeve 48s is limited, since the piston surface 48ps will meet a stop 2stop provided within the outer housing 2 (fig. 1). Applications of the well tool device 1The above well tool device 1 with the actuation system 10 may be used for a number of applications. Some embodiments will be described further in detail below. Embodiment 1: Shatter valve device It is now referred to fig. 10. Here it is shown a cross section of a shatter valve device 100. The upper section of the shatter valve device 100 is identical to the well tool device 1 described above.Below the well tool device 1, the shatter valve device 100 comprises a plug device 101. The plug device 101 has two states, a closed state and a final open state. The plug device 101 comprises an outer housing 102 being connected to or being a part of the outer housing of the well tool device 1. The outer housings 2 typically comprises an upper connection interface for connection to sections of a completion string, while the outer housing 102 typically comprises a lower connection interface for connection to sections of the same completion string. Inside the outer housing 102, a sleeve section 120 is provided below the inner housing 20. The sleeve section 120 comprises a through bore 121 aligned with the bore 21 of the inner housing 20 and hence also with the bore 48b of the second actuating device 48. The sleeve section 120 is sealingly engaged within the outer housing 102. A frangible glass body 130 is sealingly engaged within the bore 121 of the sleeve section 12 in the closed state. Hence, longitudinal fluid flow between a location above the frangible glass body 130 and a location below the frangible glass body 130 is prevented. Below the frangible glass body 130, a disintegration device 140 is seated within the sleeve section 120. The plug device 101 further comprises a retaining sleeve 141 for retaining the frangible glass body 130 within the sleeve section 120. The retaining sleeve 141 is mechanically connected to the second actuator 48 by means of an actuation rod 142 provided within a bore of the outer housing 102. To avoid unintentional movement of the actuation rod 142, the actuation rod 142 is secured to the outer housing 102 by means of a shear element 143.When the entire completion string has been assembled, the completion string is tested by increasing the fluid pressure within the completion string above the frangible glass body 130. After the test, the pressure cycling process described above is performed to bring the well tool device 1 to its final state S3, causing the second actuator 48 to move downwardly. This will push the actuation rod 142 downwardly, causing the shear element 143 to be sheared off, and causing the retaining sleeve 141 to be released from the sleeve section 120. The frangible glass body 130 will now be pushed downwardly into contact with the disintegration device 140, which disintegrates the frangible glass body 130. The plug device 101 is now in its final open state. Now, longitudinal fluid flow through the entire shatter valve device 100 is allowed. Embodiment 2: Shatter valve device with bypass fluid lineThe shatter valve device 100 with bypass fluid line is almost identical to the shatter valve device 100 described above. The shatter valve device 100 with bypass fluid line has three states, an initial open state in addition to the above closed state and final open state. In this embodiment the sleeve section 120 is longitudinally displaceable within the outer housing 102. The sleeve section 120 has a first opening 151 above the frangible glass body 130 and a second opening 152 below the frangible glass body 130. The outer housing 102 of the plug device 101 comprises a longitudinal bypass fluid line 153. In the initial open state, the sleeve section 120 is in a position (not shown) where longitudinal fluid flow between the bore 121 above the frangible glass body 130 and the bore 121 below the frangible glass body 130 is allowed via the first opening 151, the second opening 152 and the bypass fluid line 153. The plug device 101 also comprises a further actuation system 160 for moving the sleeve section 120 from the position of the initial open state to the position shown in fig. 10. The further actuation system 160 may be a known actuation system, such as the one used in the Interwell IRBV discussed in the background section. LIST OF REFERENCE NUMBERS1well tool device2outer housing2r31arecesses2r31brecess2rAC1arecess2rAC1brecess2rAC2arecess2rAC2brecess2sinner surface2stopstop10actuating system20inner housing20llower section20mmain section20nupper neck section21bore24tooth24r1first ratchet element24r2second ratchet element28locking elements28alocking elements29second fluid line30first locking mechanism31liquid-filled compartment32first fluid line32afirst section32bsecond section33piston sleeve33rrecess34pressure counter34cclutch34rclutch rod34r1first ratchet element34r2second ratchet element34rodchamber rod34rodssealing elements34sspring-biased sleeve34spsprings34t1upper tooth34t2lower tooth35locking element38first actuator38isinclining surface38ssealing elements40second locking mechanism43locking segment43agroove43brball receiving recess43isinclining surface47rotation preventing lock47bsspring-biased ball segment48second actuator48alocking elements48bbore48pspiston surface48rsrecess48sactuator sleeve100shatter valve device101plug device102outer housing120sleeve section121bore130frangible glass body140disintegration device141retaining sleeve142actuation rod143shear element151first opening152second opening153bypass fluid line160further actuating systemA38arrowA43arrowA48arrowAC1first chamberAC2second chamberD34Afirst downward directionD34Bsecond upward directionD34r1distanceD36sdistanceD38distanceD48distanceLCAlongitudinal centre axisORoverlapping regionS0initial stateS1first unlocked stateS2second unlocked stateS3final stateαangle
Claims
1. A well tool device (1) for a well, wherein the well tool device (1) comprises:- an outer housing (2); - an inner housing (20) provided radially inside the outer housing (2), wherein the inner housing (20) comprises a longitudinal through bore (21); - an actuation system (10) for operating the well tool device (1) between a plurality of operational states, wherein the plurality of operational states comprise an initial state (S0), a first unlocked state (S1), a second unlocked state (S2), and a final state (S3);wherein the actuation system (10) comprises a first locking mechanism (30), the first locking mechanism (30) including a first actuator (38) that is locked in the initial state (S0) and unlocked in the first unlocked state (S1), the second unlocked state (S2), and the final state (S3), wherein well tool device (1) is configured to be brought from the initial state (S0) to the first unlocked state (S1) by applying a first predefined fluid pressure within the bore (21);wherein the actuation system (10) comprises a second locking mechanism (40), the second locking mechanism (40) including a second actuator (48) that is locked in the initial state (S0) and the first unlocked state (S1) and that is unlocked in the second unlocked state (S2) and the final state (S3), and wherein the well tool device (1) is configured to be brought from the first unlocked state (S1) to the second unlocked state (S2) by applying a second predefined fluid pressure within the bore (21) to cause the first actuator (38) to move (A38) into engagement with the second locking mechanism (40); and wherein the well tool device (1) is configured to be brought from the second unlocked state (S2) to the final state (S3) by applying a third predefined fluid pressure within the bore (21) to cause the second actuator (48) to move (A48) relative to the inner housing (20).
2. The well tool device (1) according to claim 1, wherein the second actuator (48) comprises an actuator sleeve (48s), and wherein the second locking mechanism (40) comprises a locking segment (43) provided radially outside of at least parts of the actuator sleeve (48s) and radially outside of at least parts of the inner housing (20), wherein the locking segment (43) is preventing movement of the actuator sleeve (48s) relative to the inner housing (20) in the initial state (S0 and in the first unlocked state (S1) and wherein the locking segment (43) is allowing movement of the actuator sleeve (48s) relative to the inner housing (20) in the second unlocked state (S2) and in the final state (S3).
3. The well tool device (1) according to claim 2, wherein the second predefined fluid pressure within the bore (21) is causing the first actuator (38) to move (A38) in a longitudinal direction into engagement with the locking segment (43) of the second locking mechanism (40).
4. The well tool device (1) according to claim 3, wherein the movement (A38) of the first actuator (38) is rotating (A43) the locking segment (43).
5. The well tool device (1) according to any one of claims 3 or 4, wherein the locking segment (43) comprises an inclining surface (43is) that the first actuator (38) engages upon movement of the first actuator (38) and / or wherein a locking segment facing end of the first actuator (38) comprises an inclining surface (38is) configured to engage the locking segment (43), in order to rotate the locking segment (43) by movement of the first actuator (38).
6. The well tool device (1) according to any one of claims 2 - 5, wherein the second actuator (48) comprises radially protruding locking elements (48a) on an outer surface thereof and wherein the inner housing (20) comprises radially protruding locking elements (28a) on an outer surface thereof, and wherein the locking segment (43) comprises complementary grooves (43a) on an inner radial surface thereof for preventing relative movement between the locking elements (48a) of the second actuator (48) and the locking elements (28a) of the inner housing (20) in the initial state (S0) and in the first unlocked state (S1).
7. The well tool device (1) according to claim 6, wherein the locking segment (43) is allowing relative longitudinal movement between the locking elements (48a) of the second actuator (48) and the locking elements (28a) of the inner housing (20) in the second unlocked state (S2) and in the final state (S3).
8. The well tool device (1) according to any one of the above claims 2 - 7, wherein the well tool device (1) comprises a first chamber (AC1) being closed in the initial state (S0) and in the first unlocked state (S1) and being open in the second unlocked state (S2) and the final state (S3), wherein the locking segment (43) is provided within the first chamber (AC1).
9. The well tool device (1) according to claim 8, wherein the second actuator (48) comprises a piston surface (48ps) on the outside of the actuator sleeve (48s); and wherein the well tool device (1) comprises a second chamber (AC2) being closed in the initial state (S0), in the first unlocked state (S1) and in the second unlocked state (S2), wherein the piston surface (48ps) is located within the second chamber (AC2).
10. The well tool device (1) according to any one of the above claims 2 - 9, wherein the second locking mechanism (40) comprises a rotation preventing lock (47) for preventing unintentional rotation of the locking segment (43) relative to the actuator sleeve (48s) and / or relative to the inner housing (20) in the initial state (S0) and in the first unlocked state (S1).
11. The well tool device (1) according to any one of the above claims, wherein the first locking mechanism (30) comprises: - a liquid-filled compartment (31) provided at least partially within the inner housing (20);- a piston sleeve (33) defining a first longitudinal end of the liquid-filled compartment (31); - a first fluid line (32) defining a second longitudinal end of the liquid-filled compartment (31); - a pressure counter (34) for counting a predetermined number of pressure increases and pressure decreases in the bore (21) representing the first predefined fluid pressure;- a locking element (35) releasably connected between the first actuator (38) and the inner housing (20); wherein the locking element (35) is preventing relative movement between the first actuator (38) and the inner housing (20) in the initial state (S0) and wherein the pressure counter (34) is configured to release the locking element (35) in order to allow relative movement between the first actuator (38) and the inner housing (20) in the first unlocked state (S1); wherein the pressure counter (34) and the locking element (35) are located within the liquid-filled compartment (31).
12. The well tool device (1) according to claim 10, wherein the first actuator (38) is provided in sealing engagement within the fluid line (32) in the initial state (S0) and in the first unlocked state (S1) and wherein the first actuator (38) is brought out of its sealing engagement within the fluid line (32) in the second unlocked state (S2) and in the final state (S3).
13. The well tool device (1) according to claim 12, wherein the first actuator (38) is brought out of sealing engagement with the fluid line (32) in the second unlocked state (S2) and in the final state (S3) due to a pressure difference between the fluid in the bore (21) and the fluid within the first chamber (AC1).
14. The well tool device (1) according to any one of claims 11 – 13, wherein the inner housing (20) comprises a second fluid line (29), wherein the second fluid line (29) is defining the second longitudinal end of the liquid-filled compartment (31) together with the first fluid line (32); wherein the pressure counter (34) comprises: - a spring-biased sleeve (34s) affected by the pressure in the bore (21); - springs (34sp) biasing the spring-biased sleeve (34s) relative to the inner housing (20); - a chamber rod (34rod) sealingly engaged in the second fluid line (29), wherein a first end of the chamber rod (34rod) is connected to the spring-biased sleeve (34s).
15. The well tool device (1) according to any one of claims 11 – 14, wherein the pressure counter (34) comprises: - a first ratchet element (34r1) having a first end connected to the spring-biased sleeve (34s); - a second ratchet element (34r2) engaged with the first ratchet element (34r1), wherein movement of the first ratchet element (34r1) relative to the second ratchet element (34r2) in a first direction (D34A) is allowed and wherein movement of the first ratchet element (34r1) relative to the second ratchet element (34r2) in a second direction (D34B) opposite of the first direction (D34A) causes the second ratchet element (34r2) to move together with the first ratchet element (34r1), wherein the second ratchet element (34r2) is in a position supporting the locking element (35) to maintain the first actuator (38) locked in the initial state (S0) and wherein the second ratchet element (34r2) is moved to a position in which the locking element (35) is not supported in the first unlocked state (S1).
16. The well tool device (1) according to claim 15, wherein the first end of the first ratchet element (34r1) is connected to the spring-biased sleeve (34s) via a clutching system (34r, 34c) allowing the spring-biased sleeve (34s) to move a longitudinal distance (D36s) being longer than a maximal allowed longitudinal distance (D34r1) for the first ratchet element (34r1) to move.
17. A shatter valve device (100), wherein the shatter valve device (100) comprises:- a well tool device (1) according to any one of the above claims; - a plug device (101) defined with a closed state and a final open state; wherein the plug device (101) comprises:- an outer housing (102) connected to or being a part of the outer housing of the well tool device (1); - a sleeve section (120) provided radially inside the outer housing (102) below or above the inner housing (20); wherein the sleeve section (120) comprises a through bore (121) aligned with the bore (21) of the inner housing (20); - a frangible glass body (130) sealingly engaged within the bore (121) of the sleeve section (121) in the closed state;- a disintegration device (140) seated within the sleeve section (120);wherein in the final state (S0), the third predefined fluid pressure within the bore (21) and the the movement of the second actuator (48) relative to the inner housing (20) are causing the frangible glass body (130) to move into contact with the disintegration device (140) and disintegrate the frangible glass body (130), thereby bringing the plug device (101) to the final open state.
18. The shatter valve device (100) according to claim 17, wherein the plug device (101) comprises a retaining sleeve (141) for retaining the frangible glass body (130) within the sleeve section (120), wherein the retaining sleeve (141) is moved longitudinally away from the frangible glass body (130) by the movement of the second actuator (48), thereby allowing the frangible glass body (130) to move into contact with the disintegration device (140).
19. The shatter valve device (100) according to claim 18, wherein the plug device (101) comprises an actuation rod (142) mechanically connecting the second actuator (48) to the retaining sleeve (141).
20. The shatter valve device (100) according to claim 17, 18 or 19, wherein the sleeve section (120) is longitudinally displaceable within the outer housing (102) and comprises a first opening (151) above the frangible glass body (130) and a second opening (152) below the frangible glass body (130) and wherein the outer housing (102) of the plug device (101) comprises a longitudinal bypass fluid line (153); wherein the plug device (101) is defined with an initial open state; wherein, in the initial open state, longitudinal fluid flow is allowed between the bore (121) above the frangible glass body (130) and the bore (121) below the frangible glass body (130) via the first opening (151), the second opening (152) and bypass fluid line (153); wherein the plug device (101) comprises a further actuation system (160) for moving the sleeve section (120) to a position in which longitudinal fluid flow through the first opening (151), the second opening (152) and bypass fluid line (153) is closed.