CA2928033C - Actuation system for an oilfield tubular handling system - Google Patents
Actuation system for an oilfield tubular handling system Download PDFInfo
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- CA2928033C CA2928033C CA2928033A CA2928033A CA2928033C CA 2928033 C CA2928033 C CA 2928033C CA 2928033 A CA2928033 A CA 2928033A CA 2928033 A CA2928033 A CA 2928033A CA 2928033 C CA2928033 C CA 2928033C
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Abstract
An actuation system for a tubular handling mechanism of a tubular handling assembly, the actuation system comprising: a mud flow path passing through rotating parts and non-rotating parts of the tubular handling assembly; a valve assembly including a valve seat in the mud flow path and a ball, the valve seat positioned to be in hydraulic driving communication with the tubular handling mechanism; and a ball drop assembly including an opening to the mud flow path through which the ball is released and wherein the ball drop assembly opening is positioned in a non- rotating part.
Description
Actuation System for an Oilfield Tubular Handling System Field of the Invention The present invention relates to an oilfield tool assembly and, in particular, to an actuation system for use during oilfield tubular string handling.
Background of the Invention During oilfield drilling and borehole completion operations tubular strings may be handled in the form of a drill string, a casing string or a liner string for drilling and/or lining the borehole, etc. To grip a tubular and the tubular string, a tubular gripping tool may be used. In some operations, such as casing drilling and/or casing running, tubular gripping tool in the form of a casing clamp may be used to grip the string at its upper end.
A tubular gripping tool may be connected for manipulation by a top drive or other device, the entire assembly being suspended in a rig or derrick by a draw works, if desired.
DMSLega1\03236 I \.00388 \2439542v I
Tubular gripping tools may include gripping means that engage the tubular being handled. Gripping means may include, for example, devices that mechanically or frictionally engage the tubular including, for example, slips, jaws, packers, expandable members, etc., catch devices that hook under a shoulder on the tubular being handled, such as elevators, etc. and/or other members that exert a mechanical or physical force or field on the tubular to engage it. Tubular gripping tools may also include spears, which are intended to extend into the bore of a tubular being handled.
An external gripping tool may include a spear positioned to extend into a tubular being handled and surrounded by gripping means that engage an outer surface of the tubular, while the spear is inserted into the inner diameter of the tubular.
An inside gripping clamp may include a spear with gripping means thereon, such that when the spear extends into the bore of a tubular being handled the gripping means arc positioned for engagement of the inner wall of the tubular.
An example of an inside gripping clamp is described in US Patent no. 6,742,584 of Appleton, and assigned to the present assignee TESCO Corporation. An example of an external gripping clamp is described in US Patent no. 6,311,792 of Scott, which is also assigned to the present assignee.
A spear of a tubular gripping clamp may carry various tubular handling mechanisms.
For example, a spear may include a seal thereabout which is selected to engage and create a seal against the inner diameter of the tubular being handled. During operation, drilling fluid, commonly called mud and which can be liquid or gas-based, is pumped down through the spear and the seal creates a seal against the inner diameter to maintain fluid pressure in the tubular string. The seal generally is passive and operates against a pressure differential.
In a well control incident, it may be desirable to shut in the well, including sealing the upper end of the tubular string. If such an incident occurs during the use of a gripping clamp, well control may be achieved by reliance on the seal about the clamp's spear.
As a next step, or where a failure of the passive seal is encountered, it may be DMSLeph 032361 \ 00388\2439542v I 2 desirable to support the tubular string in the floor of the derrick/rig and to remove the casing clamp from the tubular, such that the tubular string can be capped. In a situation where both the draw works and the spear seal fail, the well may be very difficult to control. In such a situation, a blow out preventer may be useful for carriage on the spear.
In addition or alternatively, a spear may carry other tubular handling mechanisms including for example, launching systems, such as for plug launching or tool release apparatus.
For spear-carried tubular handling mechanisms, such as a well control system or a launching system, an actuation system may be required to control the operation of the system. Because the tubular handling mechanism is carried on the spear, it may be necessary that at least a portion of the actuation mechanism be carried on the spear.
Because the spear is often a rotating part, actuation mechanisms for spear-carried tubular handling mechanisms can add to the complexity of tubular handling systems.
Summary of the Invention In accordance with one aspect of the present invention, there is provided an actuation system for a tubular handling mechanism of a tubular handling assembly, the actuation system comprising: a mud flow path passing through rotating parts and non-rotating parts of the tubular handling assembly; a valve assembly including a valve seat in the mud flow path and a ball, the valve seat positioned to be in hydraulic driving communication with the tubular handling mechanism; and a ball drop assembly including an opening to the mud flow path through which the ball is released and wherein the ball drop assembly opening is positioned in a non-rotating part.
In accordance with another broad aspect of the present invention, there is provided an oilfield tubular handling system for manipulating tubulars comprising: a vertically DMS1.ega1 032361 \0018812430542v1 3 movable power drive assembly for providing rotary movement; a longitudinally extending output shaft rotatably turned about its longitudinal axis by the power drive assembly and movable vertically therewith; a pipe gripping mechanism coupled to and driven by the output shaft, the pipe gripping mechanism having a lower end selected to grip and rotate an end of the tubular segment; a mud line connected to the vertically moveable power drive assembly; a mud flow path flowing through the mud line, the power drive assembly, the longitudinally extending output shaft and then through the pipe gripping mechanism; a valve seat positioned in the mud flow path to create a high pressure condition upstream of the valve seat; and a ball drop assembly selected to release a ball to seat on the valve seat and positioned to release the ball to the mud flow path upstream of the longitudinally extending output shaft.
It is to be understood that other aspects of the present invention will become readily apparent to those skilled in the art from the following detailed description, wherein various embodiments of the invention are shown and described by way of illustration.
As will be realized, the invention is capable for other and different embodiments and its several details are capable of modification in various other respects, all without departing from the spirit and scope of the present invention. Accordingly the drawings and detailed description are to be regarded as illustrative in nature and not as restrictive.
Brief Description of the Drawings Referring to the drawings wherein like reference numerals indicate similar parts throughout the several views, several aspects of the present invention are illustrated by way of example, and not by way of limitation, in detail in the figures, wherein:
Figure 1 is a schematic illustration of a hydraulic actuation system installed in a tubular handling assembly.
DMSLcga1\032361ยต00388 \ 2439542v I 4 Figure 2 is a schematic illustration of a blow out preventer assembly on an installed tubular gripping tool and including a hydraulic actuation system.
Figure 3 is an axial section along a tubular gripping tool including a primary seal and a backup expandable seal, with the left hand side showing the backup seal in a non-expanded condition and the right hand side showing the backup seal in an expanded condition.
Figure 4 is an axial section along a portion of a tubular gripping tool including a primary seal and a backup expandable seal, with the left hand side showing the backup seal in a non-expanded condition and the right hand side showing the backup seal in an expanded condition.
Figures 5A and 5B are axial sections through a ball launch assembly useful in the present invention.
Description of Various Embodiments The detailed description set forth below in connection with the appended drawings is intended as a description of various embodiments of the present invention and is not intended to represent the only embodiments contemplated by the inventor. The detailed description includes specific details for the purpose of providing a comprehensive understanding of the present invention. However, it will be apparent to those skilled in the art that the present invention may be practiced without these specific details.
Referring to Figure 1, an oilfield tubular handling system 1 is shown for manipulating tubulars and which includes an actuator system. The oilfield tubular handling system includes a vertically movable power drive assembly 3, a longitudinally extending output shaft 4, a pipe gripping mechanism 5, a mud line 6 and an actuation system including a valve seat 7 and a ball drop assembly 8.
DtvISLegal \ 03236 I \ 00388 \ 2419542v I 5 The power drive assembly 3 is operable to provide rotary drive to various parts of the tubular handling system including longitudinally extending output shaft 4 and pipe gripping mechanism 5. In particular, output shaft 4 is rotatably turned about its longitudinal axis x by, and is movable vertically with, the power drive assembly. Pipe gripping mechanism 5 is coupled to and driven by the output shaft. The pipe gripping mechanism has a lower end 5a selected to grip and rotate an end of a tubular segment 14.
Mud line 6 is connected to power drive assembly 3 and acts as a conduit for a mud flow to the power drive assembly. In particular, mud line 6 forms part of a mud flow path flowing from a supply, first through the mud line, then through a passage 3a of the power drive assembly, through a passage 4a of the longitudinally extending output shaft and then through the a passage 5b through pipe gripping mechanism 5.
An actuator system for actuating a tubular handling mechanism 9 is also provided.
The actuator includes valve seat 7 positioned in the mud flow path useful to catch a ball 8a released from ball drop assembly 8 to create a high pressure condition upstream of the valve seat. The ball drop assembly is selected to release a ball to seat on the valve seat. To facilitate and simplify the handling, operation and construction of the tubular handling system, the ball drop assembly is positioned in a non-rotating portion of the tubular handling system. During operation, the power drive assembly will drive output shaft 4 and pipe gripping mechanism 5, which is secured to the output shaft, to rotate. Thus, at least a portion of the power drive assembly and the mud line will be non-rotating portions of the tubular handling system. As such, the ball drop assembly may be positioned to release ball 8a to the mud flow path upstream of passage 4a of output shaft 4. To avoid the complexity of the power drive assembly, it may be useful to install the ball drop assembly upstream of the power drive assembly wash pipe/swivel 3b. In the illustrated embodiment, ball drop assembly 8 is positioned in a portion of the mud line, commonly known as the Kelly hose 6a. Seat 7 may be positioned anywhere along passages 3a, 4a, 5b or in a tool connected therebelow, but for actuation of many tubular handling mechanisms, will WASLegaA032361\0038812439542v1 6 generally be positioned in passages 4a or 5b. As such, ball 8a is sized to pass through the ID of all of the mud lines 6, and through any necessary passages 3a, 4a and 5b to reach and land in seat 7.
As will be appreciated, ball 8a may be a ball, a dart, a plug or other device that can pass through the mud flow path to reach seat 7, but is selected, as by sizing and material selection, to be stopped by and sealed against the seat. It is to be understood that a ball drop assembly can operate in many different ways, for example, by various mechanisms that may not be adversely affected by normal drilling or tubular running operations and conditions, but may be actuated automatically or manually, directly or remotely when a ball is to be released. Assembly 9 may include a port to load one or more balls to a holding area and may include remotely or directly operated handles, gates or valves, remotely or directly actuated solenoids, etc.
While various ball launch assemblies may be of use in the present invention, one useful ball launch assembly is illustrated in Figures 5a and 5b to facilitate understanding. In this illustrated embodiment, assembly includes a body 160 for positioning inline in a stand pipe or kelly hose. Body 160 includes a bore 162 therethrough for placement in communication with the mud flow path arrow A. A
ball launching housing 164 is sized to accommodate a ball 166 in a ball holding area 168, which can be loaded through a port 170. Ball holding area 168 is open to bore 162, but is configured to retain ball 166 until it is desired that the ball be launched into bore 162 and, thereby, into mud flow path. In the illustrated embodiment, the ball is injected into bore 162 by a launch mechanism including a plunger 172.
The ball launch assembly of the presently illustrated embodiment also includes a purge and flush mechanism to facilitate injection and operation of the assembly. In particular, the ball launch assembly includes a valve 174 and a purge outlet 176.
While valve 174 is normally open to permit flow from inlet end 162a to outlet end I 62b of the bore, the valve may be selected to open inlet end 162a to purge outlet 176 to permit a purge flow through bore 162, the valve and the purge outlet to clear the DMSLega1\032361\00168\2439542v1 7 bore of fluids, such as cement, that may adversely affect injection of ball 166 or to initiate the flow of a second fluid behind the ball. The illustrated ball launch assembly also includes a flushing feature including a flushing channel 176 between bore 162 and ball holding area 168, through which a flushing fluid flow, arrow F, may be passed to clean area 168.
The ball drop assembly and the ball seat may be part of an actuation system for an oilfield tubular handling mechanism 9. The oilfield tubular handling mechanism may take various forms and serve various purposes. In one embodiment, for example, the actuation system may serve to release a component, such as a plug, a cement float, a drop bar, a used portion which is no longer of use, from the gripping device into a tubular being handled. In another embodiment, the oilfield tubular handling mechanism may be a hydraulically operated component such as a seal, a tool release, etc. The actuating system may operate as by use of any of a pressure communicating port, a piston, a sliding sleeve, a valve, shear pins, etc. In the illustrated embodiment, for example, tubular handling mechanism 9 includes a part 9a intended to be released from lower end 5a of the pipe gripping mechanism when it is desired to release the part. In the illustrated embodiment, tubular handling mechanism 9 includes a sliding sleeve 9b on which seat 7 is positioned. Sleeve 9b may be conveyed by a high pressure condition, as is caused by ball 8 landing in seat 7, to break shear pins 9c, positioned to hold part 9a, such that the part is released from the pipe gripping mechanism and can pass down into the tubular.
Referring to Figure 2, a tubular handling system is shown including a tubular handling mechanism in the form of a blow out preventer assembly 10 for operating between a spear 22 of a tubular gripping tool, such as a casing clamp 12 of the external gripping type, as shown, or internal gripping type (Figure 3), and a tubular 14 gripped capable of being gripped by gripping means 15 on the clamp 12. Clamp 12 may be connected for manipulation by a power drive assembly, such as for example, a top drive 16 or other device. The entire assembly of top drive 16 and clamp 12 may be suspended in a rig or derrick 18 by a draw works 20.
DMSLega1\032361 \00388 \2439542v I 8 A mud flow path may be defined by lines and pipes 21a, commonly termed a standpipe 28 and a kelly hose, on the rig extending between a mud supply and the top drive, a passage through the top drive 21b and an axial bore 21c through the clamp that opens at an end of a clamp spear 22 disposed in the tubular, when a tubular is gripped. The mudflow path provides that drilling fluid can be pumped from a mud supply to the tubular. A passive seal 19 may be mounted about the spear to act against fluids migrating up between the spear and the tubular during normal operations.
In a well control incident such as a well kick or other pressure surge from the formation, it may be desirable to shut in the well, including sealing the upper end of the tubular string. If such an incident occurs during the use of an inside gripping clamp and the passive seal about the clamp and the draw works fails, the blow out preventer assembly 10 can be operated to create a seal between the clamp and the tubular inner wall, to in effect seal the upper end of the tubular string.
The blow out preventer assembly may include an expandable seal 23 carried on the tubular gripping tool, the seal being expandable to seal between the tool and the tubular's inner wall. Seal 23 is not normally driven out into engagement with the inner wall of the tubular, but only when it is necessary to contain a surge from the formation. The seal may be selectively expandable, for example, by a hydraulic drive. A hydraulic drive may be provided, for example, by means of a system according to the present invention.
In the embodiment of Figure 2, for example, expandable seal 23 may be mounted between a retainer and a piston 26 and can be driven by applying hydraulic pressure against piston 26 such that it is driven against the seal to cause it to extrude outwardly. The actuator system for driving the piston may include a ball drop mechanism 24a including a ball 24b that is sized to pass from mechanism 24a through the mud flow path to a ball valve seat 24c to cause a seal in bore 21c through the DMSLegal \ 032361\00388 \ 2419542, I 9 clamp. Seat 24c is positioned in bore 21c downstream of a port 25 communicating hydraulic pressure to the piston. In this position, a ball launched to seal against the seat can be used to increase the fluid pressure against the piston to drive it against seal 23.
Ball drop mechanism 24a is positioned upstream of any rotating parts including the clamp and the top drive. In this embodiment, the ball drop mechanism is positioned in a standpipe 28 adjacent the rig floor, which facilitates access thereto.
The ball 24b is sized to pass through the ID of all of the mud flow lines 21a, through the top drive passage 21b and through axial bore 21c of the clamp spear to reach seat 24c.
As will be appreciated, ball 24b may be a ball, a dart, a plug or other device that can pass through the mud flow path, but is selected, as by sizing and material selection, to be stopped by and sealed against the seat. A ball drop mechanism can operate in many different ways, for example, by various mechanisms that may not be adversely affected by normal drilling or tubular running operations and conditions, but may be actuated automatically or manually, directly or remotely when a ball is to be released.
Mechanisms may include, remotely or directly operated handles, gates or valves, remotely or directly actuated solenoids, etc.
Thus, the embodiment of Figure 2 provides a method for shutting in a well during use of a tubular gripping tool and when it remains with its spear positioned in the upper end of a tubular string extending into the well, which may occur during a well incident and when the passive seal of the clamp fails and the draw works cannot be operated to remove the clamp from the end of the tubing string. The method can include expanding an clamp spear expandable seal, such as seal 23, which is positioned about a spear for example spear 22 of the tubular gripping tool to create a seal between the spear and the inner diameter of the tubular string, thereby to seal the upper end of the tubular string.
DMSLegul \ 032;6110038812439542v I 10 The expandable seal may be expanded by a drive system that can be actuated selectively when it is desired to expand the seal. Various drive mechanisms may be useful, such as an arrangement that uses drilling mud to drive expansion, as in Figures
Background of the Invention During oilfield drilling and borehole completion operations tubular strings may be handled in the form of a drill string, a casing string or a liner string for drilling and/or lining the borehole, etc. To grip a tubular and the tubular string, a tubular gripping tool may be used. In some operations, such as casing drilling and/or casing running, tubular gripping tool in the form of a casing clamp may be used to grip the string at its upper end.
A tubular gripping tool may be connected for manipulation by a top drive or other device, the entire assembly being suspended in a rig or derrick by a draw works, if desired.
DMSLega1\03236 I \.00388 \2439542v I
Tubular gripping tools may include gripping means that engage the tubular being handled. Gripping means may include, for example, devices that mechanically or frictionally engage the tubular including, for example, slips, jaws, packers, expandable members, etc., catch devices that hook under a shoulder on the tubular being handled, such as elevators, etc. and/or other members that exert a mechanical or physical force or field on the tubular to engage it. Tubular gripping tools may also include spears, which are intended to extend into the bore of a tubular being handled.
An external gripping tool may include a spear positioned to extend into a tubular being handled and surrounded by gripping means that engage an outer surface of the tubular, while the spear is inserted into the inner diameter of the tubular.
An inside gripping clamp may include a spear with gripping means thereon, such that when the spear extends into the bore of a tubular being handled the gripping means arc positioned for engagement of the inner wall of the tubular.
An example of an inside gripping clamp is described in US Patent no. 6,742,584 of Appleton, and assigned to the present assignee TESCO Corporation. An example of an external gripping clamp is described in US Patent no. 6,311,792 of Scott, which is also assigned to the present assignee.
A spear of a tubular gripping clamp may carry various tubular handling mechanisms.
For example, a spear may include a seal thereabout which is selected to engage and create a seal against the inner diameter of the tubular being handled. During operation, drilling fluid, commonly called mud and which can be liquid or gas-based, is pumped down through the spear and the seal creates a seal against the inner diameter to maintain fluid pressure in the tubular string. The seal generally is passive and operates against a pressure differential.
In a well control incident, it may be desirable to shut in the well, including sealing the upper end of the tubular string. If such an incident occurs during the use of a gripping clamp, well control may be achieved by reliance on the seal about the clamp's spear.
As a next step, or where a failure of the passive seal is encountered, it may be DMSLeph 032361 \ 00388\2439542v I 2 desirable to support the tubular string in the floor of the derrick/rig and to remove the casing clamp from the tubular, such that the tubular string can be capped. In a situation where both the draw works and the spear seal fail, the well may be very difficult to control. In such a situation, a blow out preventer may be useful for carriage on the spear.
In addition or alternatively, a spear may carry other tubular handling mechanisms including for example, launching systems, such as for plug launching or tool release apparatus.
For spear-carried tubular handling mechanisms, such as a well control system or a launching system, an actuation system may be required to control the operation of the system. Because the tubular handling mechanism is carried on the spear, it may be necessary that at least a portion of the actuation mechanism be carried on the spear.
Because the spear is often a rotating part, actuation mechanisms for spear-carried tubular handling mechanisms can add to the complexity of tubular handling systems.
Summary of the Invention In accordance with one aspect of the present invention, there is provided an actuation system for a tubular handling mechanism of a tubular handling assembly, the actuation system comprising: a mud flow path passing through rotating parts and non-rotating parts of the tubular handling assembly; a valve assembly including a valve seat in the mud flow path and a ball, the valve seat positioned to be in hydraulic driving communication with the tubular handling mechanism; and a ball drop assembly including an opening to the mud flow path through which the ball is released and wherein the ball drop assembly opening is positioned in a non-rotating part.
In accordance with another broad aspect of the present invention, there is provided an oilfield tubular handling system for manipulating tubulars comprising: a vertically DMS1.ega1 032361 \0018812430542v1 3 movable power drive assembly for providing rotary movement; a longitudinally extending output shaft rotatably turned about its longitudinal axis by the power drive assembly and movable vertically therewith; a pipe gripping mechanism coupled to and driven by the output shaft, the pipe gripping mechanism having a lower end selected to grip and rotate an end of the tubular segment; a mud line connected to the vertically moveable power drive assembly; a mud flow path flowing through the mud line, the power drive assembly, the longitudinally extending output shaft and then through the pipe gripping mechanism; a valve seat positioned in the mud flow path to create a high pressure condition upstream of the valve seat; and a ball drop assembly selected to release a ball to seat on the valve seat and positioned to release the ball to the mud flow path upstream of the longitudinally extending output shaft.
It is to be understood that other aspects of the present invention will become readily apparent to those skilled in the art from the following detailed description, wherein various embodiments of the invention are shown and described by way of illustration.
As will be realized, the invention is capable for other and different embodiments and its several details are capable of modification in various other respects, all without departing from the spirit and scope of the present invention. Accordingly the drawings and detailed description are to be regarded as illustrative in nature and not as restrictive.
Brief Description of the Drawings Referring to the drawings wherein like reference numerals indicate similar parts throughout the several views, several aspects of the present invention are illustrated by way of example, and not by way of limitation, in detail in the figures, wherein:
Figure 1 is a schematic illustration of a hydraulic actuation system installed in a tubular handling assembly.
DMSLcga1\032361ยต00388 \ 2439542v I 4 Figure 2 is a schematic illustration of a blow out preventer assembly on an installed tubular gripping tool and including a hydraulic actuation system.
Figure 3 is an axial section along a tubular gripping tool including a primary seal and a backup expandable seal, with the left hand side showing the backup seal in a non-expanded condition and the right hand side showing the backup seal in an expanded condition.
Figure 4 is an axial section along a portion of a tubular gripping tool including a primary seal and a backup expandable seal, with the left hand side showing the backup seal in a non-expanded condition and the right hand side showing the backup seal in an expanded condition.
Figures 5A and 5B are axial sections through a ball launch assembly useful in the present invention.
Description of Various Embodiments The detailed description set forth below in connection with the appended drawings is intended as a description of various embodiments of the present invention and is not intended to represent the only embodiments contemplated by the inventor. The detailed description includes specific details for the purpose of providing a comprehensive understanding of the present invention. However, it will be apparent to those skilled in the art that the present invention may be practiced without these specific details.
Referring to Figure 1, an oilfield tubular handling system 1 is shown for manipulating tubulars and which includes an actuator system. The oilfield tubular handling system includes a vertically movable power drive assembly 3, a longitudinally extending output shaft 4, a pipe gripping mechanism 5, a mud line 6 and an actuation system including a valve seat 7 and a ball drop assembly 8.
DtvISLegal \ 03236 I \ 00388 \ 2419542v I 5 The power drive assembly 3 is operable to provide rotary drive to various parts of the tubular handling system including longitudinally extending output shaft 4 and pipe gripping mechanism 5. In particular, output shaft 4 is rotatably turned about its longitudinal axis x by, and is movable vertically with, the power drive assembly. Pipe gripping mechanism 5 is coupled to and driven by the output shaft. The pipe gripping mechanism has a lower end 5a selected to grip and rotate an end of a tubular segment 14.
Mud line 6 is connected to power drive assembly 3 and acts as a conduit for a mud flow to the power drive assembly. In particular, mud line 6 forms part of a mud flow path flowing from a supply, first through the mud line, then through a passage 3a of the power drive assembly, through a passage 4a of the longitudinally extending output shaft and then through the a passage 5b through pipe gripping mechanism 5.
An actuator system for actuating a tubular handling mechanism 9 is also provided.
The actuator includes valve seat 7 positioned in the mud flow path useful to catch a ball 8a released from ball drop assembly 8 to create a high pressure condition upstream of the valve seat. The ball drop assembly is selected to release a ball to seat on the valve seat. To facilitate and simplify the handling, operation and construction of the tubular handling system, the ball drop assembly is positioned in a non-rotating portion of the tubular handling system. During operation, the power drive assembly will drive output shaft 4 and pipe gripping mechanism 5, which is secured to the output shaft, to rotate. Thus, at least a portion of the power drive assembly and the mud line will be non-rotating portions of the tubular handling system. As such, the ball drop assembly may be positioned to release ball 8a to the mud flow path upstream of passage 4a of output shaft 4. To avoid the complexity of the power drive assembly, it may be useful to install the ball drop assembly upstream of the power drive assembly wash pipe/swivel 3b. In the illustrated embodiment, ball drop assembly 8 is positioned in a portion of the mud line, commonly known as the Kelly hose 6a. Seat 7 may be positioned anywhere along passages 3a, 4a, 5b or in a tool connected therebelow, but for actuation of many tubular handling mechanisms, will WASLegaA032361\0038812439542v1 6 generally be positioned in passages 4a or 5b. As such, ball 8a is sized to pass through the ID of all of the mud lines 6, and through any necessary passages 3a, 4a and 5b to reach and land in seat 7.
As will be appreciated, ball 8a may be a ball, a dart, a plug or other device that can pass through the mud flow path to reach seat 7, but is selected, as by sizing and material selection, to be stopped by and sealed against the seat. It is to be understood that a ball drop assembly can operate in many different ways, for example, by various mechanisms that may not be adversely affected by normal drilling or tubular running operations and conditions, but may be actuated automatically or manually, directly or remotely when a ball is to be released. Assembly 9 may include a port to load one or more balls to a holding area and may include remotely or directly operated handles, gates or valves, remotely or directly actuated solenoids, etc.
While various ball launch assemblies may be of use in the present invention, one useful ball launch assembly is illustrated in Figures 5a and 5b to facilitate understanding. In this illustrated embodiment, assembly includes a body 160 for positioning inline in a stand pipe or kelly hose. Body 160 includes a bore 162 therethrough for placement in communication with the mud flow path arrow A. A
ball launching housing 164 is sized to accommodate a ball 166 in a ball holding area 168, which can be loaded through a port 170. Ball holding area 168 is open to bore 162, but is configured to retain ball 166 until it is desired that the ball be launched into bore 162 and, thereby, into mud flow path. In the illustrated embodiment, the ball is injected into bore 162 by a launch mechanism including a plunger 172.
The ball launch assembly of the presently illustrated embodiment also includes a purge and flush mechanism to facilitate injection and operation of the assembly. In particular, the ball launch assembly includes a valve 174 and a purge outlet 176.
While valve 174 is normally open to permit flow from inlet end 162a to outlet end I 62b of the bore, the valve may be selected to open inlet end 162a to purge outlet 176 to permit a purge flow through bore 162, the valve and the purge outlet to clear the DMSLega1\032361\00168\2439542v1 7 bore of fluids, such as cement, that may adversely affect injection of ball 166 or to initiate the flow of a second fluid behind the ball. The illustrated ball launch assembly also includes a flushing feature including a flushing channel 176 between bore 162 and ball holding area 168, through which a flushing fluid flow, arrow F, may be passed to clean area 168.
The ball drop assembly and the ball seat may be part of an actuation system for an oilfield tubular handling mechanism 9. The oilfield tubular handling mechanism may take various forms and serve various purposes. In one embodiment, for example, the actuation system may serve to release a component, such as a plug, a cement float, a drop bar, a used portion which is no longer of use, from the gripping device into a tubular being handled. In another embodiment, the oilfield tubular handling mechanism may be a hydraulically operated component such as a seal, a tool release, etc. The actuating system may operate as by use of any of a pressure communicating port, a piston, a sliding sleeve, a valve, shear pins, etc. In the illustrated embodiment, for example, tubular handling mechanism 9 includes a part 9a intended to be released from lower end 5a of the pipe gripping mechanism when it is desired to release the part. In the illustrated embodiment, tubular handling mechanism 9 includes a sliding sleeve 9b on which seat 7 is positioned. Sleeve 9b may be conveyed by a high pressure condition, as is caused by ball 8 landing in seat 7, to break shear pins 9c, positioned to hold part 9a, such that the part is released from the pipe gripping mechanism and can pass down into the tubular.
Referring to Figure 2, a tubular handling system is shown including a tubular handling mechanism in the form of a blow out preventer assembly 10 for operating between a spear 22 of a tubular gripping tool, such as a casing clamp 12 of the external gripping type, as shown, or internal gripping type (Figure 3), and a tubular 14 gripped capable of being gripped by gripping means 15 on the clamp 12. Clamp 12 may be connected for manipulation by a power drive assembly, such as for example, a top drive 16 or other device. The entire assembly of top drive 16 and clamp 12 may be suspended in a rig or derrick 18 by a draw works 20.
DMSLega1\032361 \00388 \2439542v I 8 A mud flow path may be defined by lines and pipes 21a, commonly termed a standpipe 28 and a kelly hose, on the rig extending between a mud supply and the top drive, a passage through the top drive 21b and an axial bore 21c through the clamp that opens at an end of a clamp spear 22 disposed in the tubular, when a tubular is gripped. The mudflow path provides that drilling fluid can be pumped from a mud supply to the tubular. A passive seal 19 may be mounted about the spear to act against fluids migrating up between the spear and the tubular during normal operations.
In a well control incident such as a well kick or other pressure surge from the formation, it may be desirable to shut in the well, including sealing the upper end of the tubular string. If such an incident occurs during the use of an inside gripping clamp and the passive seal about the clamp and the draw works fails, the blow out preventer assembly 10 can be operated to create a seal between the clamp and the tubular inner wall, to in effect seal the upper end of the tubular string.
The blow out preventer assembly may include an expandable seal 23 carried on the tubular gripping tool, the seal being expandable to seal between the tool and the tubular's inner wall. Seal 23 is not normally driven out into engagement with the inner wall of the tubular, but only when it is necessary to contain a surge from the formation. The seal may be selectively expandable, for example, by a hydraulic drive. A hydraulic drive may be provided, for example, by means of a system according to the present invention.
In the embodiment of Figure 2, for example, expandable seal 23 may be mounted between a retainer and a piston 26 and can be driven by applying hydraulic pressure against piston 26 such that it is driven against the seal to cause it to extrude outwardly. The actuator system for driving the piston may include a ball drop mechanism 24a including a ball 24b that is sized to pass from mechanism 24a through the mud flow path to a ball valve seat 24c to cause a seal in bore 21c through the DMSLegal \ 032361\00388 \ 2419542, I 9 clamp. Seat 24c is positioned in bore 21c downstream of a port 25 communicating hydraulic pressure to the piston. In this position, a ball launched to seal against the seat can be used to increase the fluid pressure against the piston to drive it against seal 23.
Ball drop mechanism 24a is positioned upstream of any rotating parts including the clamp and the top drive. In this embodiment, the ball drop mechanism is positioned in a standpipe 28 adjacent the rig floor, which facilitates access thereto.
The ball 24b is sized to pass through the ID of all of the mud flow lines 21a, through the top drive passage 21b and through axial bore 21c of the clamp spear to reach seat 24c.
As will be appreciated, ball 24b may be a ball, a dart, a plug or other device that can pass through the mud flow path, but is selected, as by sizing and material selection, to be stopped by and sealed against the seat. A ball drop mechanism can operate in many different ways, for example, by various mechanisms that may not be adversely affected by normal drilling or tubular running operations and conditions, but may be actuated automatically or manually, directly or remotely when a ball is to be released.
Mechanisms may include, remotely or directly operated handles, gates or valves, remotely or directly actuated solenoids, etc.
Thus, the embodiment of Figure 2 provides a method for shutting in a well during use of a tubular gripping tool and when it remains with its spear positioned in the upper end of a tubular string extending into the well, which may occur during a well incident and when the passive seal of the clamp fails and the draw works cannot be operated to remove the clamp from the end of the tubing string. The method can include expanding an clamp spear expandable seal, such as seal 23, which is positioned about a spear for example spear 22 of the tubular gripping tool to create a seal between the spear and the inner diameter of the tubular string, thereby to seal the upper end of the tubular string.
DMSLegul \ 032;6110038812439542v I 10 The expandable seal may be expanded by a drive system that can be actuated selectively when it is desired to expand the seal. Various drive mechanisms may be useful, such as an arrangement that uses drilling mud to drive expansion, as in Figures
2, or a system using another form of hydraulic pressure.
It may be useful to test the operation of the seal, since it may only be used occasionally, but when used may be of great importance. In a test, for example, it may be useful to conduct a flow test wherein a ball 24b is pumped from its release point to ensure that it can pass to seat without being obstructed.
With reference to Figure 3, another tubular handling system is shown including tubular handling mechanism in the form of a blow out preventer assembly. In Figure
It may be useful to test the operation of the seal, since it may only be used occasionally, but when used may be of great importance. In a test, for example, it may be useful to conduct a flow test wherein a ball 24b is pumped from its release point to ensure that it can pass to seat without being obstructed.
With reference to Figure 3, another tubular handling system is shown including tubular handling mechanism in the form of a blow out preventer assembly. In Figure
3, the blow out preventer is installed on an inside gripping clamp 112. Clamp may be used for gripping an oilfield tubular 114 and may include an end 139 formed for connection to a top drive or other means for manipulating and/or suspending the clamp in a rig. Clamp 112 may include a spear 122 sized to extend into the bore of the tubular to be gripped, gripping slips 140, or other gripping means, positioned on the spear and drivable to engage the tubular to be gripped, a bore 121 through the clamp and its spear through which drilling fluid can pass into the tubular and a primary seal 142 about the spear to create a seal between the spear the inner wall of the tubular. Primary seal 142 may be expandable in response to an at least operationally generated fluid pressure differential in the tubular. Clamp 112 may further include a secondary seal 123 about the spear which is selectively operable to create a seal between the spear the inner wall of the tubular and, therefore, may be operated as a blow out preventer as a back up to primary seal 142. An enlarged view of the portion of the clamp about the primary and secondary seals is shown in Figure
4.
As will be appreciated, clamp 112 may include any or all of the various additional parts shown in the illustrated embodiment such as a stabbing guide, a mud saver DMSLegah 032361\00388 \ 2439542v I II
valve, a tubular stop flange, etc. Slips 140 and the drive system for the slips may take various forms, including those forms illustrated, In normal operation of clamp 112, spear 122 is inserted into a tubular bore to grip the tubular during connection to or break out from a tubular string. When spear 122 is inserted into a tubular, primary seal 142 may seal against the inner wall of the tubular to contain drilling fluids in the tubular. In this normal operation, secondary seal 123 is maintained in a non-expanded condition such that it remains spaced from or not actively sealed against the tubular inner wall. This is shown in the left hand quarter sections of Figures 3 and 4.
Should a back up for primary seal 142 be necessary, seal 123 can be expanded to seal against the tubular inner wall.
Although many drive systems are possible, the drive system illustrated in Figures 3 and 4, acts by release of a ball 124c from a ball drop mechanism positioned in a non-rotating part of the top drive or mud lines somewhere upstream of a seat 124d in bore 121. Ball 124c may be pumped with the drilling mudflow into the clamp to seal against seat 124b so that mud pressure can be used to inflate the seal.
Seal 123, as in the illustrated embodiment, may be an extrudable ring packer mounted between a fixed retainer ring 150 and a piston ring 124a, shown as a two-part arrangement including a piston face 152. Piston face 152 may be open in a hydraulic chamber 154 in fluid communication with bore 121. Piston ring 124a may be secured in position by one or more shear pins 156. Shear pins 156 may be selected to prevent movement of piston 124a under normal pressures but to permit movement when fluid pressures in excess of a selected rating are applied against face 152. An example of normal operational pressure where the packer would not be activated is 3,000 psi. In this case the shear pins may be set to actuate at 3,500 to 3,750 psi. A
ratchet arrangement 158 may be disposed between spear 122 and piston ring 124a to lock the piston into its pressure driven, energized position.
DMSLegall032361 \0038812439542v I 12 As noted, pressures sufficient to shear pins 156 may be applied by landing a ball 124c against seat 124d such that pressure can be increased above the ball. This increased pressure may be communicated, arrows P. to chamber 154 and against face 152.
Induced movement of piston 124a causes seal 123 to extrude out, arrow E, between the piston and retainer 150.
The various parts of the tubular handling system and actuator system may be made of materials, and with methods, conducive to use in the oilfield industry, as will be appreciated.
The previous description of the disclosed embodiments is provided to enable any person skilled in the art to make or use the present invention. Various modifications to those embodiments will be readily apparent to those skilled in the art, and the generic principles defined herein may be applied to other embodiments without departing from the spirit or scope of the invention. Thus, the present invention is not intended to be limited to the embodiments shown herein, but is to be accorded the full scope consistent with the claims, wherein reference to an element in the singular, such as by use of the article "a" or "an" is not intended to mean "one and only one" unless specifically so stated, but rather "one or more". All structural and functional equivalents to the elements of the various embodiments described throughout the disclosure that are know or later come to be known to those of ordinary skill in the art are intended to be encompassed by the elements of the claims. Moreover, nothing disclosed herein is intended to be dedicated to the public regardless of whether such disclosure is explicitly recited in the claims. No claim element is to be construed under the provisions of 35 USC 112, sixth paragraph, unless the element is expressly recited using the phrase "means for" or "step for".
MISLegal\032361 \00388 \2439542v1 13
As will be appreciated, clamp 112 may include any or all of the various additional parts shown in the illustrated embodiment such as a stabbing guide, a mud saver DMSLegah 032361\00388 \ 2439542v I II
valve, a tubular stop flange, etc. Slips 140 and the drive system for the slips may take various forms, including those forms illustrated, In normal operation of clamp 112, spear 122 is inserted into a tubular bore to grip the tubular during connection to or break out from a tubular string. When spear 122 is inserted into a tubular, primary seal 142 may seal against the inner wall of the tubular to contain drilling fluids in the tubular. In this normal operation, secondary seal 123 is maintained in a non-expanded condition such that it remains spaced from or not actively sealed against the tubular inner wall. This is shown in the left hand quarter sections of Figures 3 and 4.
Should a back up for primary seal 142 be necessary, seal 123 can be expanded to seal against the tubular inner wall.
Although many drive systems are possible, the drive system illustrated in Figures 3 and 4, acts by release of a ball 124c from a ball drop mechanism positioned in a non-rotating part of the top drive or mud lines somewhere upstream of a seat 124d in bore 121. Ball 124c may be pumped with the drilling mudflow into the clamp to seal against seat 124b so that mud pressure can be used to inflate the seal.
Seal 123, as in the illustrated embodiment, may be an extrudable ring packer mounted between a fixed retainer ring 150 and a piston ring 124a, shown as a two-part arrangement including a piston face 152. Piston face 152 may be open in a hydraulic chamber 154 in fluid communication with bore 121. Piston ring 124a may be secured in position by one or more shear pins 156. Shear pins 156 may be selected to prevent movement of piston 124a under normal pressures but to permit movement when fluid pressures in excess of a selected rating are applied against face 152. An example of normal operational pressure where the packer would not be activated is 3,000 psi. In this case the shear pins may be set to actuate at 3,500 to 3,750 psi. A
ratchet arrangement 158 may be disposed between spear 122 and piston ring 124a to lock the piston into its pressure driven, energized position.
DMSLegall032361 \0038812439542v I 12 As noted, pressures sufficient to shear pins 156 may be applied by landing a ball 124c against seat 124d such that pressure can be increased above the ball. This increased pressure may be communicated, arrows P. to chamber 154 and against face 152.
Induced movement of piston 124a causes seal 123 to extrude out, arrow E, between the piston and retainer 150.
The various parts of the tubular handling system and actuator system may be made of materials, and with methods, conducive to use in the oilfield industry, as will be appreciated.
The previous description of the disclosed embodiments is provided to enable any person skilled in the art to make or use the present invention. Various modifications to those embodiments will be readily apparent to those skilled in the art, and the generic principles defined herein may be applied to other embodiments without departing from the spirit or scope of the invention. Thus, the present invention is not intended to be limited to the embodiments shown herein, but is to be accorded the full scope consistent with the claims, wherein reference to an element in the singular, such as by use of the article "a" or "an" is not intended to mean "one and only one" unless specifically so stated, but rather "one or more". All structural and functional equivalents to the elements of the various embodiments described throughout the disclosure that are know or later come to be known to those of ordinary skill in the art are intended to be encompassed by the elements of the claims. Moreover, nothing disclosed herein is intended to be dedicated to the public regardless of whether such disclosure is explicitly recited in the claims. No claim element is to be construed under the provisions of 35 USC 112, sixth paragraph, unless the element is expressly recited using the phrase "means for" or "step for".
MISLegal\032361 \00388 \2439542v1 13
Claims (2)
1. An actuation system for a tubular handling mechanism of a tubular handling assembly, the actuation system comprising: a mud flow path passing through rotating parts and non-rotating parts of the tubular handling assembly; a valve assembly including a valve seat in the mud flow path and a ball, the valve seat positioned to be in hydraulic driving communication with the tubular handling mechanism; and a ball drop assembly including an opening to the mud flow path through which the ball is released and wherein the ball drop assembly opening is positioned in a non-rotating part, wherein the tubular handling assembly comprises a top drive, and wherein the ball drop assembly is positioned upstream of the top drive relative to the mud flow path.
2. An oilfield tubular handling system for manipulating tubulars comprising: a vertically movable power drive assembly for providing rotary movement; a longitudinally extending output shaft rotatably turned about its longitudinal axis by the power drive assembly and movable vertically therewith; a pipe gripping mechanism coupled to and driven by the output shaft, the pipe gripping mechanism having a lower end selected to grip and rotate an end of the tubular segment;
a mud line connected to the vertically moveable power drive assembly; a mud flow path flowing through the mud line, the power drive assembly, the longitudinally extending output shall and then through the pipe gripping mechanism; a valve seat positioned in the mud flow path to create a high pressure condition upstream of the valve seat; and a ball drop assembly selected to release a ball to seat on the valve seat and positioned to release the ball to the mud flow path upstream of the longitudinally extending output shaft and upstream of the power drive assembly.
a mud line connected to the vertically moveable power drive assembly; a mud flow path flowing through the mud line, the power drive assembly, the longitudinally extending output shall and then through the pipe gripping mechanism; a valve seat positioned in the mud flow path to create a high pressure condition upstream of the valve seat; and a ball drop assembly selected to release a ball to seat on the valve seat and positioned to release the ball to the mud flow path upstream of the longitudinally extending output shaft and upstream of the power drive assembly.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US82618906P | 2006-09-19 | 2006-09-19 | |
| US60/826,189 | 2006-09-19 | ||
| CA2560828A CA2560828C (en) | 2006-09-19 | 2006-09-25 | Actuation system for an oilfield tubular handling system |
Related Parent Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2560828A Division CA2560828C (en) | 2004-03-19 | 2006-09-25 | Actuation system for an oilfield tubular handling system |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2928033A1 CA2928033A1 (en) | 2008-03-19 |
| CA2928033C true CA2928033C (en) | 2018-05-01 |
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ID=39190399
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2560828A Active CA2560828C (en) | 2004-03-19 | 2006-09-25 | Actuation system for an oilfield tubular handling system |
| CA2928033A Active CA2928033C (en) | 2006-09-19 | 2006-09-25 | Actuation system for an oilfield tubular handling system |
Family Applications Before (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2560828A Active CA2560828C (en) | 2004-03-19 | 2006-09-25 | Actuation system for an oilfield tubular handling system |
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| Country | Link |
|---|---|
| CA (2) | CA2560828C (en) |
-
2006
- 2006-09-25 CA CA2560828A patent/CA2560828C/en active Active
- 2006-09-25 CA CA2928033A patent/CA2928033C/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CA2928033A1 (en) | 2008-03-19 |
| CA2560828A1 (en) | 2008-03-19 |
| CA2560828C (en) | 2016-06-14 |
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Effective date: 20160419 |