Wellbore control apparatus, connection device and method
阅读说明:本技术 井眼控制设备、连接装置和方法 (Wellbore control apparatus, connection device and method ) 是由 斯图尔特·埃利森 于 2014-06-16 设计创作,主要内容包括:本发明涉及一种井眼控制设备,该井眼控制设备包括:壳体,其限定用于容纳管状件的通孔;第一闸门和第二闸门,在使用中第一闸门和第二闸门能够沿横向于通孔的方向在通孔的打开位置和通孔的关闭位置之间移动;第一致动器,其包括第一致动器壳体和连接于第一闸门的第一闸门致动器,以用于在打开位置和关闭位置之间移动第一闸门;第二致动器,第二致动器具有第二致动器壳体和连接于第二闸门的第二闸门致动器,以用于在打开位置和关闭位置之间移动第二闸门;以及连接装置,其用于将第一致动器壳体和第二致动器壳体彼此固定和/或紧固。本发明还涉及用于将井眼控制设备的第一致动器和第二致动器连接、固定和/或紧固在一起的方法以及连接装置。(The present invention relates to a wellbore control device comprising: a housing defining a through-hole for receiving a tubular member; a first gate and a second gate, the first gate and the second gate being movable in use in a direction transverse to the through-hole between an open position of the through-hole and a closed position of the through-hole; a first actuator including a first actuator housing and a first gate actuator connected to the first gate for moving the first gate between an open position and a closed position; a second actuator having a second actuator housing and a second gate actuator connected to the second gate for moving the second gate between the open position and the closed position; and a connecting device for fixing and/or fastening the first actuator housing and the second actuator housing to each other. The invention also relates to a method and a connection device for connecting, securing and/or fastening together a first actuator and a second actuator of a wellbore control device.)
1. A wellbore control apparatus, comprising:
a housing defining a through-hole for receiving a tubular member;
a first gate and a second gate, the first gate and the second gate being movable in a direction transverse to the through-hole between an open position of the through-hole and a closed position of the through-hole, in use;
a first actuator including a first actuator housing and a first gate actuator connected to the first gate for moving the first gate between the open position and the closed position;
a second actuator having a second actuator housing and a second gate actuator connected to the second gate for moving the second gate between the open position and the closed position; and
a connecting means for securing and/or fastening the first and second actuator housings to one another.
2. A wellbore control apparatus according to claim 1, wherein the connection means is arranged to bias and/or draw the first and second actuator housings towards each other.
3. A wellbore control apparatus according to claim 2, wherein the connection means is arranged to bias and/or draw the first and second actuator housings towards each other in the longitudinal direction of the housings.
4. A wellbore control apparatus according to any of the preceding claims, wherein the connection means biases and/or draws the first and second actuator housings inwardly and/or towards the through bore.
5. A wellbore control apparatus according to any preceding claim, wherein, in use, the first and second actuators are actuated at least partially outwardly as the first and second gates move from an open position to a closed position of the through bore.
6. A wellbore control apparatus according to any preceding claim, wherein, in use, the first and second actuators generate or exert an outward force and/or load on the first and second actuator housings, such as in a direction away from the through bore.
7. A wellbore control apparatus according to any preceding claim, wherein, in use, when the first and second gates are moved to the closed position, the forces and/or loads exerted by the connection device on the first and second actuator housings are in opposite or opposite directions to the forces and/or loads exerted by the first and second actuators on the first and second actuator housings.
8. A wellbore control apparatus according to any preceding claim, wherein, in use, the connection means provides a loading path for forces and/or loads acting on the first and second actuator housings and/or the housings.
9. A wellbore control apparatus according to any preceding claim, wherein, in use, the connection means minimises or prevents movement of the first and second actuator housings, such as outward movement, when the first and second actuators respectively move or actuate the first and second gates from an open to a closed position of a through-bore.
10. A wellbore control apparatus according to any of the preceding claims, wherein the connection device is arranged outside the through-bore and extends in a longitudinal direction of the housing, the first actuator housing and/or the second actuator housing.
11. A wellbore control apparatus according to any preceding claim, wherein the connection means comprises one or more elongate members.
12. A wellbore control apparatus according to any preceding claim, wherein each of the one or more elongate members comprises a first portion and a second portion, the first and second portions extending from the respective first and/or second actuator housings.
13. A wellbore control apparatus according to claim 12, wherein the connection means comprises one or more connectors adapted to connect together the first and second portions of the one or more elongate members respectively.
14. A wellbore control apparatus according to claim 13, wherein the one or more connections are adapted to adjust and/or vary the tension acting between the respective first and second portions of the one or more elongate members and/or the first and second actuator housings.
15. A method for connecting, securing and/or fastening together a first actuator section and a second actuator section of a wellbore control device, the method comprising:
providing a wellbore control device according to claims 1-14;
the first actuator housing and the second actuator housing are connected, secured and/or fastened together with a connecting device.
16. The method of connecting, securing and/or fastening together a first actuator housing and a second actuator housing of a wellbore control apparatus of claim 15, wherein the step of connecting, securing and/or fastening together the first actuator housing and the second actuator housing comprises: the first and second portions of one or more elongated members are connected together using one or more connectors, the elongated members being disposed on or extending from respective first and second actuator housings.
17. A method for connecting, securing and/or fastening together first and second actuator housings of a wellbore control apparatus according to claim 15 or 16, wherein the method comprises: minimizing and/or limiting movement of the first and second actuator housings, such as outward movement, when the respective first and second actuators move or actuate the first and second gates from an open position to a closed position of a through-bore.
18. A method of connecting, securing and/or fastening together first and second actuator housings of a wellbore control apparatus according to any of claims 15 to 17, wherein the force and/or load exerted by the connecting means on the first and second actuator housings has an opposite or opposite direction to the force and/or load exerted by the first and second actuators on the first and second actuator housings when the first and second gates are actuated or moved from an open to a closed position of a through bore.
19. A method of connecting, securing and/or fastening together first and second actuator housings of a wellbore control apparatus according to any of claims 15 to 18, wherein the method comprises adjusting and/or varying the tension acting between the respective first and second portions of the one or more elongate members and/or the first and second actuator housings.
20. A connection means for connecting, securing and/or fastening together a first actuator housing and a second actuator housing of a wellbore control apparatus according to any of claims 1 to 14.
Technical Field
The present invention relates to a wellbore control apparatus for sealing a wellbore, and more particularly, but not exclusively, for sealing a wellbore having a tubular (such as a workover or drilling conductor) or a servicing tool passing therethrough. The invention also relates to a method and a connection device for connecting, securing and/or fastening together a first actuator and a second actuator of a wellbore control device.
Background
In the oil and gas industry, production or exploration wells are provided with one or more wellbore control devices, such as blowout preventers or riser control devices for sealing the wellbore in case of emergency to protect personnel and the environment.
Wellbore control devices are mostly blowout preventers (BOPs) and include various sets of rams. Among these, there are generally three basic types: pipe rams for closing around a pipe or tubular passing through a wellbore control device; a blind ram for sealing the wellbore without a tubular passing through the wellbore control device; and shear rams for severing any tubular present in the wellbore. All of the rams of the set are installed perpendicular to the wellbore, with the wellbore oriented vertically. When a Blowout (Blowout) occurs in the well due to an overpressure condition, shear rams may be activated to shear a tubular disposed within the wellbore and passing through the wellbore control device, thereby sealing the wellbore and preventing flooding of well fluids. The shear rams are actuated to move in a horizontal plane and are driven by in-line pistons. Most of the existing BOPs and wellbore control devices have various disadvantages, for example, sealing is typically achieved with elastomeric seals, which are limited when more aggressive wells having high temperature and high pressure fluids need to be inhibited. In addition, the conventional in-line piston structure is very large and heavy, is difficult to maneuver, and is expensive to manufacture.
Sealing of the wellbore can be improved by using a valve to seal the through-hole. However, most available valves (e.g., ball valves with hardened cutting edges) are only capable of severing a very limited range of tubular members or conduits, and most of them are of a small diameter of 2-3 inches, such as coiled tubing.
GB2454850B discloses an improved wellbore control valve which is more compact than conventional BOPs in which the cutting gate and actuator are arranged in parallel to reduce the overall length of the device. Operating the actuator to pull the cutting blade and the gate in opposite directions through the borehole, thereby providing a shear force to sever a tubular within the borehole; the gate then seals the well and engages two separate seals to provide a separate metal-to-metal seal.
There is a need for further improvements in the aforementioned wellbore control devices to further improve sealability, seal maintenance and replacement, and general device maintenance.
Disclosure of Invention
According to a first aspect of the present invention there is provided a wellbore control apparatus comprising:
a housing having a guide element for defining a path, the housing defining a through-hole for receiving a tubular member;
a first and a second conical gate located within the housing and adapted to engage with the guide element, wherein, in use, upon application of an actuating force, the first and second conical gates are movable along a path defined by the guide element in a direction substantially perpendicular to the through-bore between an open position of the through-bore and a closed position of the through-bore; and
and the first sealing seat is used for forming a first seal with the first gate in the closed position so as to seal the through hole.
The wellbore control apparatus may comprise a second sealing seat. The second sealing seat may be adapted to form a second seal with the second gate in the closed position to seal the through-hole.
The first seal and/or second seal may minimize or prevent fluid flow through the through-bore, such as wellbore fluid.
The guide element may be arranged to: in use, the guide element actuates the first and/or second gate to sealingly engage the first and/or second gate with the first and/or second seal seat, respectively, in the closed position. For example, in the closed position, the first and/or second gate may abut the first and/or second seal seat, respectively, to form the first and/or second seal. By providing a guide element to actuate the first and/or second gate into sealing engagement with the first and/or second seal seat respectively, the through bore may be sealed when either of the first and second gates is in the closed position. Alternatively or additionally, the through-hole is sealed when both the first and second gates are in the closed position.
The guide element may cause displacement of the first and/or second gate in a direction perpendicular to the generally lateral movement of the first and/or second gate when the first and/or second gate is moved from the open position to the closed position. The displacement of the first shutter and/or the second shutter caused by the guide element is in a direction parallel to the through hole. Displacement of the first and/or second gate deflects material within the corresponding first and/or second seal seat to energize the first and/or second seal.
The guide element actuates the first and second gates such that the first and second gates provide first and second seals independently of each other in the closed position. By arranging the first and second gates to seal the through-bore independently of each other in the closed position, a wellbore control device with fail-safe may be provided.
The tapered portions of the first and second gates may cause the first and second gates to coact with each other when the first and second gates are in the closed position.
The guide element may be disposed in the housing in a direction generally transverse to the through-hole. The guide element may be inclined or declined relative to the longitudinal axis of the housing. The guide element may be disposed in the housing to define an acute angle with respect to a longitudinal axis of the housing.
In some embodiments, the guide element may have a protrusion, groove and/or recess, such as an elongated protrusion, groove and/or recess. The one projection, groove and/or recess is disposed within the housing in a direction generally transverse to the through-hole. In other embodiments, the guide element may have a plurality of protrusions, grooves and/or recesses, such as elongated protrusions, grooves and/or recesses. The plurality of protrusions, grooves and/or recesses may be disposed within the housing in a direction generally transverse to the through-hole. Each of the plurality of protrusions, grooves and/or recesses may be arranged parallel to one another.
The housing may comprise one or more guide elements. In some embodiments, the housing may include a first guide element and a second guide element. The first guide member and the second guide member are disposed within the housing and oppose each other. For example, the first and second guide elements may be provided on two opposing surfaces within the housing.
The first gate and/or the second gate may be adapted to engage with the guide element. The first gate and/or the second gate comprise an engagement element. The engaging element may be provided on the first shutter and/or the second shutter. The engagement element is arranged for mating, interacting and/or co-acting with the guide element of the housing. In some embodiments, the engagement element may have one further protrusion, groove and/or recess, for example for matching, interacting and/or co-acting with a corresponding protrusion, groove and/or recess of the guide element. In other embodiments, the engagement element may have a plurality of further protrusions, grooves and/or recesses, for example for matching, interacting and/or co-acting with a corresponding plurality of protrusions, grooves and/or recesses of the guide element. In some embodiments, the engagement element is co-linear or aligned with the tapered portion of the first and/or second gate.
The first gate and/or the second gate may comprise one or more engagement elements. The plurality of engagement elements may be arranged for mating, interacting and/or co-acting with one or more guide elements of the housing. In some embodiments, the first and/or second gate may have a first and second engagement element. The first and second engagement members are disposed on opposite sides or faces of the first and/or second gate. The first and second engagement elements may be provided on the first and/or second gate to mate, interact and/or cooperate with the respective first and second guide elements of the housing.
The engaging element may be provided on the first gate and/or the second gate along the length or longitudinal direction of the first gate and/or the second gate. The engagement element may be inclined or declined relative to the longitudinal axis of the first and/or second gate. The engagement element may be provided on the first gate and/or the second gate to define an acute angle with respect to a longitudinal axis of the first gate and/or the second gate.
In some embodiments, the acute angle defined by the engagement element may be the same as the acute angle defined by the guide element. In other embodiments, the acute angle defined by the engagement element may be different from the acute angle defined by the guide element.
The first gate and/or the second gate may comprise a first metal gate and/or a second metal gate. The first and/or second seal seats may comprise first and/or second metal seal seats. In the closed position, the first and/or second gate engages or abuts the respective first and/or second seal seat to form a respective first and/or second metal-to-metal seal.
In the closed position, the first and/or second gate and/or the first and/or second engagement element may engage or abut the guide element and/or housing to form a further first and/or second seal, such as a further first and/or second metal-to-metal seal, between the first and/or second gate and the guide element and/or housing.
The first gate and/or the second gate may comprise a first shearing element and/or a second shearing element, respectively. The first and/or second shearing element may be provided at an end of the respective first and/or second gate. The first shearing element and/or the second shearing element may be adapted to sever a tubular contained within the through bore. For example, the first shearing element and/or the second shearing element may sever a tubular contained within the through bore as the first gate and/or the second gate moves from the open position to the closed position.
The wellbore control apparatus may comprise a first gate actuator and/or a second gate actuator. The first gate actuator and/or the second gate actuator may be contained in the housing. The first and/or second gate actuators may be connected to the first and/or second gates, respectively, to move the first and/or second gates between the open and closed positions.
According to a second aspect, there is provided a wellbore control apparatus comprising:
a housing defining a through-hole for receiving a tubular member;
a first gate and a second gate movable, in use, in a direction transverse to the through-hole between an open position of the through-hole and a closed position of the through-hole;
a first actuator section including a first gate actuator connected to the first gate for moving the first gate between the open and closed positions;
a second actuator portion having a second shutter actuator connected to the second shutter for moving the second shutter between the open position and the closed position; and
a connecting means for fixing and/or securing the first and second actuator parts to each other.
The first and/or second actuator parts may be part of a housing. The first and second actuator portions (in other embodiments, defined as pistons) may be coaxially disposed within the housing. The first and second actuator parts may be disposed outside the through-hole.
The linkage is arranged to bias and/or draw the first and second actuator parts towards each other. The connecting means may be arranged to bias and/or draw the first and second actuator parts towards each other in the longitudinal direction of the housing. The connecting means may bias and/or draw said first and second actuator parts inwards or towards the through hole. The connection means may generate or apply an inward force and/or load (e.g. a force and/or load towards the through hole) at the first and second actuator parts.
In use, the first and second actuators are actuated at least partially outwardly when the first and second gates are moved from the open position to the closed position of the through-bore. In use, the first and second actuators generate or exert an outward force and/or load on the first and second actuator parts, such as a force and/or load in a direction away from the through-hole. For example, an outward force and/or load may act on the first and second actuator portions when the first and second actuators (e.g., pistons) move the respective first and second shutters into the closed position.
In use, when the first and second gates are moved to the closed position, the force and/or load exerted by the linkage on the first and second actuator portions has an opposite or opposite direction to the force and/or load exerted by the first and second actuators on the first and second actuator portions.
In use, the connection means provides a loading path for forces and/or loads acting on the first and second actuator parts and/or the housing. In use, the connection means minimises or prevents movement (e.g. outward movement) of the first and second actuator portions when the first and second pistons respectively move or actuate the first and second shutters from the open to the closed position of the through bore away from the through bore.
The connecting device is arranged outside the through hole. The connecting means may extend in the longitudinal direction of the housing, the first actuator part and/or the second actuator part. The connecting means may comprise one or more elongate members. Each of the one or more elongated members includes a first portion and a second portion. A first portion of each of the one or more elongate members is disposed on or extends from the first actuator portion. A second portion of each of the one or more elongate members is disposed on or extends from a second actuator portion. The first portion and the second portion of each of the one or more elongated members are disposed opposite each other. In some embodiments, the first and second portions of the one or more elongate members may include a threaded arrangement (e.g., threads, etc.).
The connecting means may comprise one or more connecting members. The one or more coupling members are adapted to couple the first and second portions of the one or more elongated members together, respectively. The one or more connectors each have additional first and second thread configurations (e.g., threads, etc.). The first and second thread formations of the one or more connectors may engage and/or cooperate with the thread formations of the first and second portions of the one or more elongate members.
The one or more connections are adapted to adjust and/or change the tension acting between the first and second actuator parts. For example, the one or more coupling members may be adapted to adjust and/or vary the tension acting between the first and second portions and/or between the first and second actuator portions of the respective one or more elongate members. For example, the tension applied between the first and second portions and/or the first and second actuator portions of the one or more elongate members may be varied by moving or rotating the one or more linkages to move or draw the first and second actuator portions together, or the tension applied between the first and second actuator portions may be released by moving or rotating the one or more linkages.
The features defined in the first aspect may be applied to this second aspect.
According to a third aspect of the invention there is provided a wellbore control apparatus comprising:
a housing having a guide element for defining a path, the housing defining a through-hole for receiving a tubular member;
a first gate and a second gate located within the housing and adapted to engage with the guide element, wherein, in use, the first gate and the second gate are movable along a path defined by the guide element in a direction substantially perpendicular to the through-bore between an open position of the through-bore and a closed position of the through-bore; and
and the first sealing seat is used for forming a first seal with the first gate in the closed position so as to seal the through hole.
The wellbore control apparatus may comprise a second sealing seat. The second sealing seat may be adapted to form a second seal with the second gate in the closed position to seal the through-hole.
The first seal and/or second seal may minimize or prevent fluid flow through the through-bore, such as wellbore fluid.
The guide element may be arranged to: in use, the guide element actuates the first and/or second gate to sealingly engage the first and/or second gate with the first and/or second seal seat, respectively, in the closed position. For example, in the closed position, the first and/or second gate may abut the first and/or second seal seat, respectively, to form the first and/or second seal. By providing a guide element to actuate the first and/or second gate into sealing engagement with the first and/or second seal seat respectively, the through bore may be sealed when either of the first and second gates is in the closed position. Alternatively or additionally, the through-hole is sealed when both the first and second gates are in the closed position.
The guide element may cause displacement of the first and/or second gate in a direction perpendicular to the generally lateral movement of the first and/or second gate when the first and/or second gate is moved from the open position to the closed position. The displacement of the first shutter and/or the second shutter caused by the guide element is in a direction parallel to the through hole. Displacement of the first and/or second gate deflects material within the respective first and/or second seal seat to energize the first and/or second seal.
The guide element actuates the first and second gates such that the first and second gates provide first and second seals independently of each other in the closed position. By arranging the first and second gates to seal the through-bore independently of each other in the closed position, a wellbore control device with fail-safe may be provided.
The guide element may be disposed in the housing in a direction generally transverse to the through-hole. The guide element may be inclined or declined relative to the longitudinal axis of the housing. The guide element may be disposed in the housing to define an acute angle with respect to a longitudinal axis of the housing.
In some embodiments, the guide element may have a protrusion, groove and/or recess, such as an elongated protrusion, groove and/or recess. The one projection, groove and/or recess is disposed within the housing in a direction generally transverse to the through-hole. In other embodiments, the guide element may have a plurality of protrusions, grooves and/or recesses, such as elongated protrusions, grooves and/or recesses. The plurality of projections, grooves and/or recesses may be disposed within the housing in a direction generally transverse to the through-hole. Each of the plurality of protrusions, grooves and/or recesses may be disposed parallel to one another.
The housing may comprise one or more guide elements. In some embodiments, the housing may include a first guide element and a second guide element. The first guide member and the second guide member are disposed within the housing and oppose each other. For example, the first and second guide elements may be provided on two opposing surfaces within the housing.
The first gate and/or the second gate may be adapted to engage with the guide element. The first gate and/or the second gate comprise an engagement element. The engaging element may be provided on the first shutter and/or the second shutter. The engagement element is arranged for mating, interacting and/or co-acting with the guide element of the housing. In some embodiments, the engagement element may have a further projection, groove and/or recess, for example for mating, interacting and/or co-acting with a corresponding projection, groove and/or recess of the guide element. In other embodiments, the engagement element may have a plurality of further protrusions, grooves and/or recesses, for example for matching, interacting and/or co-acting with a corresponding plurality of protrusions, grooves and/or recesses of the guide element. In some embodiments, the engagement element is co-linear or aligned with the tapered portion of the first and/or second gate.
The first gate and/or the second gate may comprise one or more engagement elements. The plurality of engagement elements may be arranged for mating, interacting and/or co-acting with one or more guide elements of the housing. In some embodiments, the first and/or second gate may have a first and second engagement element. The first and second engagement members are disposed on opposite sides or faces of the first and/or second gate. The first and second engagement elements may be provided on the first and/or second gate to mate, interact and/or cooperate with the respective first and second guide elements of the housing.
The engaging element may be provided on the first gate and/or the second gate along the length or longitudinal direction of the first gate and/or the second gate. The engagement element may be inclined or declined relative to the longitudinal axis of the first and/or second gate. The engagement element may be provided on the first gate and/or the second gate to define an acute angle with respect to a longitudinal axis of the first gate and/or the second gate.
In some embodiments, the acute angle defined by the engagement element may be the same as the acute angle defined by the guide element. In other embodiments, the acute angle defined by the engagement element may be different from the acute angle defined by the guide element.
The first gate and/or the second gate may comprise a first metal gate and/or a second metal gate. The first and/or second seal seats may comprise first and/or second metal seal seats. In the closed position, the first and/or second gate engages or abuts the respective first and/or second seal seat to form a respective first and/or second metal-to-metal seal.
In the closed position, the first and/or second gate and/or the first and/or second engagement element may engage or abut the guide element and/or housing to form a further first and/or second seal, such as a further first and/or second metal-to-metal seal, between the first and/or second gate and the guide element and/or housing.
The first gate and/or the second gate may comprise a first shearing element and/or a second shearing element, respectively. The first and/or second shearing element may be provided at an end of the respective first and/or second gate. The first shearing element and/or the second shearing element may be adapted to sever a tubular contained within the through bore. For example, the first shearing element and/or the second shearing element may sever a tubular contained within the through bore as the first gate and/or the second gate moves from the open position to the closed position.
The wellbore control apparatus may comprise a first gate actuator and/or a second gate actuator. The first gate actuator and/or the second gate actuator may be contained in the housing. The first and/or second gate actuators may be connected to the first and/or second gates, respectively, to move the first and/or second gates between the open and closed positions.
The features defined in the first and/or second aspects may be applied to this third aspect.
According to a fourth aspect of the invention there is provided a method for sealing a wellbore, the method comprising:
providing a wellbore control device according to the first aspect;
actuating or moving the first shutter and/or the second shutter in a direction transverse to the through hole from an open position of the through hole to a closed position of the through hole;
engaging the first gate with the first seal seat; and
and forming a first seal between the first gate and the first seal seat to seal or close the through hole.
The first seal may minimize or prevent fluid flow through the through-bore, such as wellbore fluid.
The method may include actuating or moving the first gate along a path defined by a guide element. The steering element is located in a housing of the wellbore control device. The guide element may actuate the first gate into sealing engagement with the first seal seat.
The method may include engaging the second gate with a second seal seat.
The method may include forming a second seal between the second gate and the second seal seat to seal or close the through-hole.
The method may include actuating or moving the second gate along a path defined by the guide element. The guide element may guide the second gate and bring it into sealing engagement with the second seat.
The features defined in the first, second and/or third aspect may be applied to this fourth aspect.
According to a fifth aspect of the invention there is provided a method for connecting, securing and/or fastening together first and second actuator parts of a wellbore control device, the method comprising:
providing a wellbore control apparatus according to the third aspect of the invention;
the first actuator part and the second actuator part are connected, fixed and/or fastened together by means of a connecting device.
The step of connecting, securing and/or fastening together the first and second actuator parts comprises: the first and second portions of one or more elongate members are connected together, for example by one or more connectors, the elongate members being disposed on or extending from respective first and second actuator portions. In some embodiments, the first and second portions of the one or more elongated members may have a threaded configuration (e.g., threads, etc.). The one or more connectors each have a first thread configuration and a second thread configuration. The first and second thread formations of the one or more coupling members may engage and/or cooperate with the thread formations of the first and second elongate members.
The method may include: when the respective first and second actuators move or actuate the first and second gates from the open position to the closed position of the through-bore, movement of the first and second actuator portions is minimized and/or limited, such as outward movement. The forces and/or loads exerted by the connecting means on the first and second actuator parts may have opposite or opposite directions to the forces and/or loads exerted by the first and second actuators on the first and second actuator parts when the first and second gates are actuated or moved from the open position to the closed position of the through-hole.
The method may comprise adjusting and/or varying the tension effect between the first and second portions and/or the first and second actuator portions of the respective one or more elongate members. For example, the tension effect between the first and second portions and/or the first and second actuator portions of the one or more elongate members may be altered by moving or rotating the one or more coupling members to move or draw the first and second actuator portions together, or the tension effect between the first and second actuator portions may be released by moving or rotating the one or more coupling members.
The features defined in the first, second, third and/or fourth aspects may be applied to this fifth aspect.
According to a sixth aspect of the invention, there is provided a connection device for connecting, securing and/or fastening together a first actuator part and a second actuator part of a wellbore control apparatus according to the second aspect of the invention.
The connecting means may comprise any feature of the second and/or fourth aspects.
According to a seventh aspect of the present invention there is provided a wellbore control apparatus comprising: a housing defining a through bore adapted to receive a tubular member, first and second gates each having a shearing member and located within the housing, the first and second gates being movable in different directions transverse to the through bore between a through bore open position and a through bore closed position, in use, to shear a tubular member located within the through bore; a first seal seat for forming a seal with the first shutter in the through hole closing position to seal the through hole; the housing has first and second gate actuators connected to respective first and second gates for moving the first and second gates between open and closed positions, the gate actuators each having a removable element to enable access to the interior of the wellbore control apparatus.
Preferably, a second sealing seat for forming a seal with the second gate is further provided.
Conveniently, each said actuator is generally hollow and is connected to an end plate which can be removed separately.
Preferably, the first and second gates have a taper such that, in use, when the gates are moved to the closed position, the tapered gates slide past each other to cause a displacement parallel to the through-bore and to cause a surface of the gate adjacent the seal to bear against the seal and energise the seal.
Conveniently, the seal is a metal seal and the gate is a metal gate, such that when the apparatus is actuated and the gate is closed, the abutment of the gate and seal forms a metal-to-metal seal. In addition, the abutment of the seal housing with the housing also provides a metal-to-metal seal.
Preferably, the first and second shutter actuators can be locked in the open position or the closed position. Conveniently, this may be achieved by providing a plurality of spring-loaded dogs biased to engage in a receiving position of the actuator, the dogs being capable of being hydraulically driven to a release position when it is desired to move the gate between the open and closed positions.
The features defined in the first, second and/or fourth aspect may be applied to this seventh aspect.
According to an eighth aspect of the present invention there is provided a wellbore control apparatus comprising: a housing defining a through-hole adapted to receive a tubular member; a first gate and a second gate located within the housing, the first gate and the second gate being movable in different directions transverse to the through bore between a through bore open position and a through bore closed position, in use, to shear a tubular located within the through bore; and a first seal seat for forming a seal with the first shutter or the second shutter at a through-hole closing position to seal the through-hole; the housing has first and second gate actuators connected to respective first and second gates, respectively, for moving the first and second gates between wellbore open and closed positions, the gate actuators each having a removable element to enable access to an interior of the wellbore control apparatus, the removable element connected to a shear ram assembly.
Conveniently, the shear ram assembly comprises a drive portion, a moving stop portion, a cutting blade and a sealing gate. Preferably, each of said sealing shutters has a tapered portion.
Preferably, the seal is a metal seal and the gate is a metal gate to provide a metal-to-metal seal when the wellbore control device is in the closed position.
Conveniently, the removable elements are connected to respective actuators and ram shear assemblies, the elements being freely movable relative to the housing to define free bores, the removable elements being fixed to a hollow piston actuator.
Preferably, the removable element is connected to the hollow piston actuator by a plurality of C-rings disposed in spaced grooves between the removable element and the actuator. Conveniently, each of the actuator and the detachable element is provided with spaced apart slots, a C-ring being provided in each pair of slots to ensure that the detachable element is stably secured to the actuator. Conveniently, the actuator or the detachable element has a plurality of slots around the circumference for receiving elements to move the C-ring to release the detachable element from the actuator to allow removal of the detachable element and associated shear ram assembly from the wellbore control apparatus.
Conveniently, the slot is provided around the periphery for receiving the element for moving the C-ring.
Alternatively, the rotatable cam mechanism may be provided with a cam surface for engaging with the C-ring, whereby rotation of the cam carrying element causes the cam surface to bear against the C-ring and in response to displacement of the cam surface the C-ring will move into the recess to allow removal of the detachable end element and associated shear ram assembly from the wellbore control apparatus.
The features defined in the first, second, third and/or seventh aspect may be applied to this eighth aspect.
According to a ninth aspect of the present invention, there is provided a mechanism for locking the position of a reciprocating piston with a hydraulic cylinder, the mechanism comprising: a housing defining a chamber for receiving a piston movable within the chamber between a first position and a second position to define a first chamber for extending the piston in the first position and a second chamber for retracting the piston in the second position, the piston and the housing having a sealing arrangement separating the first and second chambers to form a third chamber disposed between the piston seals and movable with movement of the piston, the first, second and third chambers being respectively connected to a hydraulic port for receiving hydraulic fluid under pressure, the piston having a spaced recess for receiving at least one locking pawl to lock the piston in the closed or open position, the at least one locking dog is positively biased into engagement with the recess of the piston to lock the piston in either the first or second position, and the locking dog is movable under hydraulic actuation into the third chamber to bias the locking dog against a spring load and allow pressure to be applied to either the first or second chamber to move the piston within the housing.
The housing is cylindrical and is provided with a plurality of spring biased locking dogs, which are arranged evenly around the circumference of the housing to engage with corresponding recesses of the cylindrical piston.
According to a tenth aspect of the present invention, there is provided another connecting device for connecting together a first body and a second body, both of which are circular, and one of which is defined as a parent body and the other as a male body, said parent body having an inner circular surface, the inner circular surface is provided with a plurality of spaced grooves, the male body is provided with a circular surface which has the diameter which is approximately the same as that of the inner surface of the female body, the male body is also provided with the same number of grooves with similar sizes, the grooves on the male body and the female body are arranged at equal intervals and are suitable for accommodating C-shaped rings, the C-ring being mounted in a groove in one of said male or female bodies, said one of said male or female bodies having a plurality of slots formed therein which intersect the circumferential groove, the slot is adapted to receive a plurality of elements for engaging the C-ring in the circumferential groove, which elements enable said C-ring to be moved to allow the disconnection of the male body from the female body.
Alternatively, the axial slot is replaced with a shaft carrying a cam surface for engagement with the groove, such that rotation of the shaft causes the cam surface to move the C-ring and allow the male body to be disconnected from the female body.
According to an eleventh aspect of the invention there is provided a method of maintaining the interior of a wellbore control apparatus according to the first aspect of the invention, the method comprising the steps of: removing an end cap of the wellbore control device, the end cap connected to the shear ram assembly, removing the end cap and shear ram assembly to allow replacement of the cutting blade, sealing gate, or valve seal.
Preferably, the method comprises moving the C-ring with a wedge to disconnect the end cap from the hollow cylindrical actuator. Optionally, the method includes moving the C-ring with the cam surface to decouple the end cap from the hollow cylindrical actuator.
Preferably, there is also included a method of improving a metal-to-metal seal with a wellbore control device, comprising: providing a metal seal gate having a tapered surface, energizing seals between a top metal seal and a first gate surface and between a bottom metal seal and a gate surface in response to closing of the wellbore control device to place the seals in a high pressure preload state.
Preferably, the method comprises forming a metal-to-metal seal with the seal housing and the seal housing.
It will be appreciated that features defined in accordance with any one of the above aspects of the invention or any one of the following specific embodiments of the invention may be used alone or in combination with any other feature of any other aspect or embodiment of the invention.
Drawings
These and other aspects of the invention will become more apparent from the following description and by reference to the accompanying drawings, in which:
FIG. 1 is a perspective view of a well control system having wellbore control devices located on a set of pipe rams;
FIG. 2 is an enlarged view of the wellbore control apparatus of FIG. 1, with the device in an open position;
FIG. 3a is a vertical cross-sectional view of the wellbore control apparatus of FIG. 2 taken along line 3-3 of FIG. 2 with the shear rams and sealing gates removed;
FIG. 3b is a partial enlarged view of FIG. 3 a;
FIG. 3c is a vertical cross-sectional view of the wellbore control apparatus of FIG. 2 taken along line 4-4;
FIG. 4 is a cross-sectional view of the apparatus of FIG. 2 taken along line 4-4;
FIG. 5 is a cross-sectional view of the device of FIG. 2 taken along line 3-3;
FIG. 6 is a vertical cross-sectional view of the device of FIG. 2 taken along line 5-5;
FIG. 7a is a vertical cross-sectional view similar to FIG. 3a, showing the lower shear ram and gate with cutting blades of the apparatus of FIG. 1 in an open position;
FIG. 7b is an enlarged isometric view of the lower gate of FIG. 7 a;
FIGS. 8a and 8b are vertical cross-sectional views similar to FIG. 7a showing the lower gate actuated by a guide element to seal the wellbore when the apparatus of FIG. 1 is in the closed position;
FIG. 9a is a vertical cross-sectional view similar to FIG. 8a showing the upper and lower gates actuated by a guide element to seal the wellbore when the apparatus of FIG. 1 is in the closed position;
FIG. 9b is a cross-sectional view similar to FIG. 5, with the device of FIG. 1 in a closed position;
FIG. 10 shows the wellbore control apparatus of FIG. 2, but with the actuator moved so that the device is in a closed position to seal the wellbore;
FIG. 11 is a cross-sectional view similar to FIG. 9b, without the guide member present, according to an embodiment of the present invention;
FIG. 12 is a vertical cross-sectional view similar to FIG. 9a, without the guide member present, according to an embodiment of the present invention;
FIG. 13 is a view similar to FIG. 6, with the guide elements absent and with the end connector plates, attached gate rods and sealing gates removed;
14a and 14b are vertical cross-sectional views of the wellbore control apparatus, with FIG. 14a showing the gate actuated in an open position and FIG. 14b showing the gate actuated in a closed position;
FIG. 15a is a vertical sectional view and diagrammatic view similar to FIGS. 14a and 14b, schematically showing a conical gate;
FIG. 15b is an enlarged detail view of the portion of FIG. 15a within the dashed box;
FIG. 16 shows a graph of pressure applied to an actuator during movement of a gate for a wellbore control device having parallel and tapered rams and for a wellbore device having gates that are pushed against each other in accordance with an embodiment of the invention;
FIGS. 17a and 17b are views similar to FIG. 2 showing the linkage of the wellbore apparatus with the wellbore apparatus in an open position in FIG. 17a and in a closed position in FIG. 17 b;
FIGS. 18a and 18b are views similar to FIGS. 15a and 15b, but with the gate stem and sealing gate removed to show internal accessibility;
19a, 19b, 19c, 19d and 19e illustrate a mechanism for locking the position of a reciprocating piston within a hydraulic cylinder to illustrate one method for locking the position of the actuator and sealing gate of the apparatus of FIGS. 1 to 18;
FIG. 20a is an enlarged, fragmentary detail view, shown in perspective, of the dashed portion of the apparatus of FIG. 6 in the direction of arrow 13, illustrating the engagement of the end plate with the actuator housing;
FIG. 20b is a schematic view showing how an insert can be used to remove an end connection plate; and
fig. 21a, 21b, 21C and 21d show the end plate with the C-ring installed in place and show in sequence how a wedge can be inserted into the slot for engaging the C-ring and the end plate removed to access the interior.
Detailed Description
Referring initially to FIG. 1, there is shown a blowout preventer (BOP) stack, generally designated by the numeral 20, including a wellbore control system provided by a
Referring now to FIG. 2, an enlarged view of the
As will be described in detail later, the ends 30 and 32 have actuators for actuating shear rams that move cutting blades and sealing gates between open and closed positions. The actuator and shutter are arranged so that in the position shown in figure 2 the shutter is in the open position and the
Referring to fig. 3a and 3b, there is shown a vertical section taken along line 3-3 in fig. 2 with the shear ram and sealing gate removed. In this embodiment, the
As can be seen from fig. 3a and 3b, the
Referring to FIG. 3c, a vertical cross-section taken along line 4-4 in FIG. 2 is shown. The
Referring now to FIG. 4, a vertical cross-section taken along line 4-4 of FIG. 2 is shown. It will be seen that the
Reference is now made to fig. 5, which shows a horizontal section of the apparatus of fig. 2. It will be seen that the
The
Each
Each
Fig. 6 shows a vertical cross-sectional view of the apparatus in fig. 2, and in this figure, an
Referring to fig. 7a and 7b, another vertical cross-sectional view of
As can be seen in fig. 7b, the
Referring to fig. 7b, grooves 69a, 69b are provided on the lower gate 64 along the length direction or longitudinal direction of the
It is understood that in other embodiments, the acute angle β may be different than the acute angle α, but it is understood that the grooves 69a, 69b define recesses 69c having sufficient space to accommodate the
As can be seen in fig. 7b,
Fig. 8a and 8b show the
As shown in fig. 8b, the
In the closed position, the engagement elements 65a, 65b of the
As can be seen in fig. 8a and 8b, by providing the
Referring to FIG. 9a,
Referring now to fig. 9a, 9b, 10, 11 and 12, the wellbore control device is shown in a closed position. Referring first to fig. 10, it can be seen that the pistons are hydraulically actuated to move the
As will be described later, the piston can be held in position regardless of whether it is in the open or closed position by using a plurality of locking
Referring now to FIG. 13, a vertical cross-sectional view of the wellbore control apparatus (similar to FIG. 6) is shown, but with the lower
Referring now to fig. 14a, 14b and 15a, 15b, the operation of the wellbore control device according to the present invention is better illustrated. The apparatus in figure 14a is shown closed with the rams in a position such that the
Referring to fig. 9, 15a and 15b, gate stops 64a, 64b are tapered in the direction of travel and are shown as enlarged
The minimum angle of the taper available is limited by the pre-load capacity of the seal and/or the stroke length of the actuator.
The maximum angle of taper available is limited by the preload requirement of the seal and/or the ability of the actuator lock.
To maximize the work transfer from the actuator to the seal preload, a small angle is preferred, but the angle must be sufficient to be compatible with the system in terms of its manufacturing and assembly tolerances.
The angle of the taper may be so small as to be imperceptible to the eye, but the gate will be sufficiently tapered to produce the required displacement component perpendicular to the direction of gate movement, which is sufficient to energise the seal.
This has the following significant advantages: once the valve is closed, the seal can be fully energized independent of any wellbore pressure or fluid stimulus and provides a very robust seal for low pressure or low density fluids. This configuration places all sealing positions of the bore in a high compressive preload condition regardless of the condition of the bore or any fluid within the bore. This provides a truly self-energizing, bi-directional metal-to-metal seal, and the high pressure pre-loaded sealing state allows the use of a full metal-to-metal seal to provide more robust and durable seal integrity.
FIG. 16 shows a graph of pressure or hydraulic force applied to an actuator (e.g.,
Referring to fig. 16, it can be seen that at about 10% of movement (a), the pressure is increased such that the actuator moves the gate from the closed position into the aperture. For ram preventers, this initial pressure is high because the wellbore pressure must be overcome to push the gate into the wellbore.
At about 20% -30% (B) of the movement, the actuator pressure increases while the tubular contained in the
In embodiments of the wellbore control apparatus having parallel gates, the seals provided by the upper and lower gates of the bore are dependent upon bore pressure or fluid stimulation. By providing the wellbore control device with a conical gate, the sealing of the wellbore is activated by the interaction and friction of the upper and
Referring to fig. 17a and 17b, there is shown an enlarged view of the apparatus of fig. 1 in an open state (fig. 17a) and in a closed state (fig. 17 b). As described with reference to fig. 2, the
The connecting means 34 is arranged to draw the first and
In fig. 17b, the inner and
Here, the
As can be seen from fig. 17a and 17b, the connecting
In this embodiment, the connecting means comprises six elongate members or tie means, three of which are shown in figures 17a and 17b and are designated by
The connecting means 34 comprises six connectors or turnbuckles 38 (three of which are shown in fig. 17a and 17b) for connecting together the first and
Rotating the turnbuckle may adjust or change the tension between the first and
Referring now to fig. 18a and 18b, similar to that shown and described in fig. 13, the end plates and associated shear ram assemblies are shown removed to allow access to the interior of the apparatus. This may be achieved by providing the
The operation of the outer piston structure shown in fig. 1 to 18 will now be described in detail with reference to fig. 19a to 19 e. It will be appreciated that since the pistons are controlled by hydraulic fluid, it is important to provide a control system which ensures that the aforementioned inner and outer pistons are maintained in position and do not reciprocate in the event of a hydraulic failure. This may be provided by a control mechanism for locking the position of the reciprocating piston within the hydraulic cylinder.
Referring to fig. 19a to 19e (which show the
As with the two
In fig. 19a it can be seen that the piston is locked in the retracted position so that the locking dogs are biased into the
Reference is now made to fig. 20a, 20b, 21a and 21b, which illustrate how the web is retained within the inner piston actuator, and how the web is removed to enable the ram assembly to allow access to the interior of the apparatus (as described with reference to fig. 12).
Referring first to fig. 20a, it can be seen that the end plates and actuators have three sets of spaced
It will be understood that various modifications may be made to the embodiments of the devices and components described above without departing from the scope of the present invention.
For example, it will be appreciated that the gate stops 64a, 64b need not be tapered, although the provision of tapered gate stops has the advantages of energizing the seals as previously described, thereby resulting in a very robust seal against low pressure or low density fluids once the valve is closed to provide better seal integrity.
The material of the blades may be inconel or any equivalent hard material sufficient to sever a tubular member or the like. Axial slots 104 (shown in fig. 20 and 21) that intersect the circumferential grooves may also be located on the actuator, as well as or instead of the
Thus, it will be appreciated that the foregoing apparatus has significant advantages over the prior art in providing stimulated seal integrity and ease of access to allow maintenance of the interior of the apparatus. The structure of the invention is such that the actuator can be removed and the gate left in place, thereby ensuring seal integrity; alternatively, it is provided that the shear rams can be removed to allow replacement of the blades and seals, thereby facilitating rapid maintenance and significantly reducing time and expense over existing structures. The foregoing structure can be used for different sizes (from 5 "-7" inch products to 18 ″)3/4Inch products), all operating on a similar principle to the previous embodiment. For example, the
For example, the grooves 69a, 69B may be lowered relative to the longitudinal axis B of the upper and/or