US20180340400A1 - System and method for rotating casing string - Google Patents
System and method for rotating casing string Download PDFInfo
- Publication number
- US20180340400A1 US20180340400A1 US16/057,185 US201816057185A US2018340400A1 US 20180340400 A1 US20180340400 A1 US 20180340400A1 US 201816057185 A US201816057185 A US 201816057185A US 2018340400 A1 US2018340400 A1 US 2018340400A1
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- tubular member
- tubular
- keys
- tool
- slots
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- 238000000034 method Methods 0.000 title claims abstract description 15
- 239000012530 fluid Substances 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 238000009434 installation Methods 0.000 description 4
- 230000000007 visual effect Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 2
- 230000000295 complement effect Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- 238000011144 upstream manufacturing Methods 0.000 description 2
- 238000007792 addition Methods 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
- E21B17/05—Swivel joints
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/04—Casing heads; Suspending casings or tubings in well heads
Definitions
- This disclosure relates in general to a tubular string such as casing string, and in particular to a system and method for rotating casing string.
- a system that includes a tool, a hanger connected to the tool, and a plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore that traverses a subterranean formation.
- Each of the tubulars is connected to at least one other tubular.
- the tool, the hanger, and the plurality of tubulars are rotatable in response to at least the application of torsion to the tool.
- the tool, the hanger, and the plurality of tubulars are rotatable without transferring torque to the connection between the tool and the hanger.
- the hanger is a casing hanger
- the plurality of tubulars is a casing string.
- the tool, the hanger, and the plurality of tubulars rotate in response to at least: the application of a tensile load across the tool; and the application of torsion to the tool during the application of the tensile load across the tool.
- any trapped torsion between any of the respective connections between any two of the tubulars in the plurality of tubulars is released in response to the application of a compressive load across the tool.
- connection between the tool and the hanger is capable of being broken without breaking any of the respective connections between any two of the tubulars in the plurality of tubulars.
- a method that includes positioning a tubular string within a wellbore that traverses a subterranean formation, the tubular string including a plurality of tubulars, each of the tubulars being connected to at least one other tubular.
- a hanger is connected to the tubular string. Torsion is applied to the tubular string to rotate the tubular string.
- a tool is connected to the hanger, and torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, without transferring torque to the connection between the tool and the hanger.
- the tubular string is a casing string
- the hanger is a casing hanger
- the tool includes a tubular member
- connecting the tool to the hanger includes connecting the tubular member to the hanger. Torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, without transferring torque to the connection between the tubular member and the hanger.
- the method includes applying a compressive load across the tool to release any trapped torsion between any of the respective connections between any two of the tubulars in the tubular string.
- the method includes breaking the connection between the tool and the hanger without breaking any of the respective connections between any two of the tubulars in the tubular string.
- applying torsion to the tubular string further includes applying a tensile load across the tool. Torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, during applying the tensile load across the tool.
- an apparatus for rotating a tubular string within a preexisting structure includes a first tubular member, a second tubular member extending within the first tubular member, a third tubular member extending within the first tubular member.
- the apparatus includes a first configuration in which: the third tubular member is in a first position relative to each of the first and second tubular members; torque is permitted to be transmitted between the second and third tubular members to connect the apparatus to, or disconnect the apparatus from, a fourth tubular member adapted to be connected to the tubular string; and torque is not permitted to be transmitted between the first and third tubular members.
- the apparatus includes a second configuration in which: the third tubular member is in a second position relative to each of the first and second tubular members; torque is not permitted to be transmitted between the second and third tubular members; and torque is permitted be transmitted between the first and third tubular members to rotate the tubular string.
- the preexisting structure is a wellbore that traverses a subterranean formation
- the fourth tubular member is a casing hanger
- the tubular string is a casing string.
- the apparatus in another exemplary embodiment, includes a torsion nut connected to the first tubular member, and the third tubular member extends through the torsion nut.
- torque is permitted to be transmitted between the first and third tubular members via at least the torsion nut.
- the third tubular member includes a first plurality of keys or slots, and a second plurality of keys or slots axially spaced from the first plurality of keys or slots.
- the second tubular member includes a third plurality of keys or slots for complementary engagement with the first plurality of keys or slots when the apparatus is in the first configuration.
- the torsion nut includes a fourth plurality of keys or slots for complementary engagement with the second plurality of keys or slots when the apparatus is in the second configuration.
- the apparatus in another exemplary embodiment, includes a torsion nut connected to one end of the first tubular member, wherein the third tubular member extends through the torsion nut.
- the first tubular member includes a fifth plurality of keys or slots at the other end thereof for transmitting torque to the tubular string to rotate the tubular string.
- the apparatus includes the fourth tubular member, the fourth tubular member including a sixth plurality of keys or slots adapted to complementarily engage the fifth plurality of keys or slots of the first tubular member.
- torque is adapted to be transmitted to the tubular string via the fourth tubular member.
- the apparatus includes a first annular groove formed in the outside surface of the third tubular member, wherein the first annular groove is generally aligned with an end of the torsion nut when the apparatus is in the first configuration, and a second annular groove formed in the outside surface of the third tubular member and axially spaced from the first annular groove, wherein the second annular groove is generally aligned with the end of the torsion nut when the apparatus is in the second configuration.
- first and second tubular members include internal and external shoulders, respectively.
- the apparatus further includes an annular support that is sandwiched between the external shoulder of the second tubular member and the internal shoulder of the first tubular member when the apparatus is in the first configuration.
- FIG. 1 is a diagrammatic view of an apparatus according to an exemplary embodiment, the apparatus including a tool, a casing hanger and a tubular string.
- FIG. 2 is an exploded perspective view of the tool and the casing hanger of FIG. 1 , according to an exemplary embodiment.
- FIG. 3 is a sectional view of the tool and the casing hanger of FIGS. 1 and 2 , according to an exemplary embodiment.
- FIG. 4 is a view similar to that of FIG. 3 , but depicts the tool in another configuration, according to an exemplary embodiment.
- FIG. 5 is a view similar to that of each of FIGS. 3 and 4 , but depicts the tool in yet another configuration, according to an exemplary embodiment.
- an apparatus is generally referred to by the reference numeral 10 and includes a hanger, such as a casing hanger 12 , to which a tool 14 is connected.
- a tubular string 16 is connected to the casing hanger 12 , and is positioned within a preexisting structure such as, for example, a wellbore 18 that traverses one or more subterranean formations.
- the tubular string 16 is a casing string, which extends within the wellbore 18 to facilitate oil and gas exploration and production operations.
- the tubular string 16 includes a plurality of tubulars, each of which is connected to at least one other tubular in the tubular string 16 . For example, as shown in FIG.
- the plurality of tubulars in the tubular string 16 includes at least tubulars 16 a , 16 b and 16 c .
- the tubular 16 a is connected to the casing hanger 12 to define a connection 20 a
- the tubular 16 b is connected to the tubular 16 a to define a connection 20 b
- the tubular 16 c is connected to the tubular 16 b to define a connection 20 c .
- each of the connections 20 a , 20 b and 20 c is a threaded engagement, with the threaded engagement being sufficiently tight so as to render the tubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through the tubular string 16 , holding pressure within the tubular string 16 , providing structural support to the wellbore 18 , one or more other intended purposes, or any combination thereof).
- each of the connections 20 a , 20 b and 20 c is a box and pin connection, with the box and pin connection being sufficiently tight so as to render the tubular string 16 sufficiently operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through the tubular string 16 , holding pressure within the tubular string 16 , providing structural support to the wellbore 18 , one or more other intended purposes, or any combination thereof).
- the tool 14 includes a first tubular member, such as an outer torsion sleeve (or outer sleeve 22 ), a second tubular member, such as a casing hanger/running tool connection sleeve (or inner sleeve 24 ), a third tubular member, such as a landing tool/running tool pup (or pup 26 ), and a torsion nut 28 .
- the tool 14 further includes an annular support 30 , a plurality of torsion keys 32 , a plurality of torsion keys 34 , and a plurality of torsion keys 36 .
- the annular support 30 is a bushing.
- the annular support 30 is a high-capacity axial bearing assembly.
- the outer sleeve 22 includes a plurality of openings 22 a formed in the bottom end thereof; respective internal threaded connections are formed in the openings 22 a .
- the torsion keys 32 include respective external threaded connections, which threadably engage with the internal threaded connections in the respective openings 22 a , thereby connecting the torsion keys 32 to the outer sleeve 22 .
- the torsion keys 32 are connected to the outer sleeve 22 using fasteners, or are integrally formed with the outer sleeve 22 .
- the outer sleeve 22 further includes an internal threaded connection 22 b at the end portion thereof opposing the openings 22 a , and an internal shoulder 22 c positioned axially between the openings 22 a and the internal threaded connection 22 b.
- the outer sleeve 22 is adapted to engage the casing hanger 12 so that the torsion keys 32 extend into respective openings 12 a formed in an external shoulder 12 b (see FIG. 2 ) of the casing hanger 12 , and so that an upper end portion 12 c of the casing hanger 12 extends within the outer sleeve 22 .
- An internal shoulder 12 d and an internal threaded connection 12 e adjacent thereto, are formed in the upper end portion 12 c of the casing hanger 12 .
- the casing hanger 12 further includes a flange 12 f , which is adapted to engage a wellhead housing (not shown), under conditions to be described below.
- the inner sleeve 24 extends within the outer sleeve 22 , and includes an external threaded connection 24 a at the lower end thereof, an external shoulder 24 b adjacent the external threaded connection 24 a , and an external shoulder 24 c above the external shoulder 24 b .
- the external threaded connection 24 a is adapted to threadably engage, and threadably disengage from, the internal threaded connection 12 e of the casing hanger 12 .
- the external shoulder 24 b is adapted to engage, and disengage from, the internal shoulder 12 d of the casing hanger 12
- the external shoulder 24 c is adapted to engage, and disengage from, the annular support 30 .
- the torsion keys 34 are positioned proximate the external shoulder 24 c , and are circumferentially spaced around, and connected to, the inner sleeve 24 .
- the torsion keys 34 are connected to the inner sleeve 24 via fasteners 38 , which extend radially inwardly into the inner sleeve 24 .
- the torsion keys 34 are connected to the inner sleeve 24 via other types of fasteners, or are integrally formed with the inner sleeve 24 .
- the pup 26 extends within the outer sleeve 22 , and includes slots 26 a formed in the lower end thereof, an internal shoulder 26 b , and an external shoulder 26 c .
- Axially-spaced annular grooves 26 d and 26 e are formed in the outside surface of the pup 26 proximate the upper end portion thereof.
- the torsion keys 36 are positioned adjacent the external shoulder 26 c , and are circumferentially spaced around, and connected to, the pup 26 .
- the torsion keys 36 are connected to the pup 26 via fasteners 40 , which extend radially inwardly into the pup 26 .
- the torsion keys 36 are connected to the pup 26 via other types of fasteners, or are integrally formed with the pup 26 .
- the pup 26 extends through the torsion nut 28 , which includes an external threaded connection 28 a , which is threadably engaged with the internal threaded connection 22 b of the outer sleeve 22 , thereby connecting the torsion nut 28 to the outer sleeve 22 .
- the torsion nut 28 further includes a flange 28 b , which engages the upper end of the outer sleeve 22 .
- Slots 28 c are formed in the lower end of the torsion nut 28 .
- the tool 14 may include annular sealing elements, such as o-rings, which are axially-spaced from one another along the tool 14 and sealingly engage components thereof.
- the apparatus 10 facilitates oil and gas exploration and production operations. More particularly, the flange 12 f of the casing hanger 12 engages a wellhead housing (not shown), and the tubular string 16 hangs from the casing hanger 12 , being positioned within the wellbore 18 .
- each of the connections 20 a , 20 b and 20 c is a threaded engagement, with the threaded engagement being sufficiently tight so as to render the tubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through the tubular string 16 , holding pressure within the tubular string 16 , providing structural support to the wellbore 18 , one or more other intended purposes, or any combination thereof).
- the tubular string 16 is in tension at least in part because it hangs from the casing hanger 12 .
- the casing hanger 12 suspends the tubular string 16 within the wellbore 18 , thereby causing the tubular string 16 to be in tension.
- the tool 14 may or may not be connected to the casing hanger 12 .
- tubular string 16 it is desired to rotate the tubular string 16 about its longitudinal axis while the tubular string 16 is in tension and positioned within the wellbore 18 .
- the rotation of the tubular string 16 may be desirable in order to, for example, allow the tubular string 16 to be installed to the desired depth in the subterranean formation(s) through which the wellbore 18 extends.
- the tool 14 is connected to the casing hanger 12 .
- the tool 14 is assembled in accordance with the foregoing, and then is moved downwards, as viewed in FIG. 3 .
- the upper end portion 12 c of the casing hanger 12 extends within the outer sleeve 22 , as shown in FIG. 3 .
- the inner sleeve 24 is moved downward within the outer sleeve 22 , as viewed in FIG. 3 , so that the external threaded connection 24 a may be threadably engaged with the internal threaded connection 12 e of the casing hanger 12 .
- the inner sleeve 24 may be so moved by moving the pup 26 downward, as viewed in FIG.
- the pup 26 may be rotated, which rotation, due to the extension of the torsion keys 34 into the respective slots 26 a , transmits torque from the pup 26 to the inner sleeve 24 , causing the inner sleeve 24 to rotate and thus the external threaded connection 24 a to be threadably engaged with the internal threaded connection 12 e , thereby connecting the inner sleeve 24 to the casing hanger 12 .
- the inner sleeve 24 continues to be rotated until the inner sleeve 24 is sufficiently connected to the casing hanger 12 , thereby connecting the tool 14 to the casing hanger 12 .
- the outer sleeve 22 engages the casing hanger 12 so that the torsion keys 32 complementarily engage, and fully extend into, the respective openings 12 a of the casing hanger 12 .
- the external shoulders 24 b and 24 c engage the internal shoulder 12 d and the annular support 30 , respectively.
- the annular support 30 is sandwiched between the external shoulder 24 c of the inner sleeve 24 and the internal shoulder 22 c of the outer sleeve 22 .
- the annular groove 26 e is generally axially aligned with the upper end of the torsion nut 28 , thereby providing an external visual indication that the inner sleeve 24 is sufficiently connected to the casing hanger 12 . In the configuration shown in FIG. 3 , no tensile load is applied across the tool 14 .
- a tensile load is applied across the tool 14 . More particularly, the pup 26 is forced to move upwards, relative to the outer sleeve 22 , the inner sleeve 24 and the torsion nut 28 , until the torsion keys 36 complementarily engage, and fully extend into, the respective slots 28 c of the torsion nut 28 , as shown in FIG. 4 . Thus, the pup 26 shoulders out when the torsion keys 36 are keyed into the respective slots 28 c . As shown in FIG.
- the annular groove 26 d is generally axially aligned with the upper end of the torsion nut 28 , thereby providing an external visual indication that the pup 26 has shouldered out against the torsion nut 28 , and thus a tensile load is being applied across the tool 14 .
- the tensile load of the tubular string 16 is transferred from the suspended tubular string 16 to the casing hanger 12 via the connection 20 a (see FIG. 1 ), from the casing hanger 12 to the inner sleeve 24 via the threaded engagement between the external threaded connection 24 a and the internal threaded connection 12 e , from the inner sleeve 24 to the outer sleeve 22 via the respective engagements between the external shoulder 24 c and the annular support 30 , and between the internal shoulder 22 c and the annular support 30 , from the outer sleeve 22 to the torsion nut 28 via the threaded engagement between the external threaded connection 28 a and the internal threaded connection 22 b , and from the torsion nut 28 to the pup 26 via the shouldering out of the pup 26 against the torsion nut 28 .
- the tensile load of the tubular string 16 is applied across the tool 14 ; as a result, the apparatus 10 is
- torsion is applied to the tubular string 16 , while the tubular string 16 is in tension and positioned within the wellbore 18 , in order to rotate the tubular string 16 within the wellbore 16 . More particularly, when the apparatus 10 is in the configuration shown in FIG. 4 and tension is applied across the tool 14 , the pup 16 is rotated about its longitudinal axis, thereby applying torsion to the tool 14 .
- the applied torsion is transmitted from the pup 26 to the torsion nut 28 via extension of the torsion keys 36 into the respective slots 28 c , from the torsion nut 28 to the outer sleeve 22 via the threaded engagement between the external threaded connection 28 a and the internal threaded connection 22 b , from the outer sleeve 22 to the casing hanger 12 via the extension of the torsion keys 32 into the respective openings 12 a , from the casing hanger 12 to the tubular 16 a via the connection 20 a (see FIG. 1 ), from the tubular 16 a to the tubular 16 b via the connection 20 b (see FIG.
- the tubular string 16 rotates about its longitudinal axis within the wellbore 18 while remaining in tension.
- the applied torsion is not transmitted or transferred to the connection between the tool 14 and the casing hanger 12 , that is, the threaded engagement between the external threaded connection 24 a and the internal threaded connection 12 e.
- the tool 14 is capable of carrying the tensile load of, and rotating, the tubular string 16 , without transferring torque to the connection between the tool 14 and the casing hanger 12 , that is, the threaded engagement between the external threaded connection 24 a of the inner sleeve 24 and the internal threaded connection 12 e of the casing hanger 12 .
- the amount of torque necessary to disconnect the inner sleeve 24 (and thus the tool 14 ) from the casing hanger 12 is not increased as a result of applying torsion to the tool 14 , the casing hanger 12 and the tubular string 16 .
- the pup 26 moves downward, as viewed in FIGS. 3 and 4 , and un-keys from the torsion nut 28 . That is, the torsion keys 36 no longer extend into the respective slots 28 c , as shown in FIG. 3 .
- any trapped torsion between any two of the tubulars e.g., the tubulars 16 a and 16 b , or the tubulars 16 b and 16 c ) in the tubular string 16 is released.
- any trapped torsion between any two of the above-described pairs of components used to transmit or transfer torque from the pup 16 to the tubular 16 c is released.
- a compressive load may be applied across the tool 14 by forcing the pup 26 to move downward, as viewed in FIG. 3 .
- a compressive load may be applied across the tool 14 by permitting the apparatus 10 to be dropped into, or landed in, the wellhead profile, and/or manipulating the apparatus 10 or components thereof so that the apparatus 10 drops into, or lands in, the wellhead profile.
- the pup 26 continues to move downward until it keys into the inner sleeve 24 , that is, the torsion keys 34 complementarily engage, and fully extend into, the respective slots 26 a of the pup 26 , as shown in FIG. 3 .
- the tool 14 may be disconnected from the casing hanger 12 .
- the pup 26 is rotated, which rotation, due to the extension of the torsion keys 34 into the respective slots 26 a , transmits torque from the pup 26 to the inner sleeve 24 , causing the inner sleeve 24 to rotate and thus break the connection between the tool 14 and the casing hanger 12 , that is, the threaded engagement between the external threaded connection 24 a and the internal threaded connection 12 e .
- the pup 26 causes the external threaded connection 24 a to be threadably disengaged from the internal threaded connection 12 e .
- the tool 14 is disconnected from the casing hanger 12 .
- the pup 26 may be forced upwards until the annular groove 26 d is generally axially aligned with the upper end of the torsion nut 28 , thereby providing an external visual indication that the inner sleeve 24 , and thus the tool 14 , is fully disconnected from the casing hanger 12 .
- This external visual indication is shown in FIG. 5 . Since the tool 14 is disconnected from the casing hanger 12 , the tool 14 may be lifted off of the casing hanger 12 so that that the torsion keys 32 no longer extend into the respective openings 12 a of the casing hanger 12 .
- connection between the tool 14 and the casing hanger 12 may be broken without breaking the connection 20 a (see FIG. 1 ), and without breaking any of the respective connections between any two of the tubulars in the tubular string 16 , such as the connection 20 b or 20 c (see FIG. 1 ).
- This is possible because the tool 14 permitted torsion to be applied to the tubular string 16 , in order to rotate the tubular string 16 within the wellbore 18 as described above, without transferring torque to the connection between the tool 14 and the casing hanger 12 .
- use of the tool 14 to rotate the tubular string 16 eliminates, or at least reduces, the risk that the connection 20 b or 20 c , or any other connections between any two tubulars in the tubular string 16 , may be broken before the connection between the tool 14 and the casing hanger 12 is broken.
- connection 20 a all connections between the tubulars in the tubular string 16 (including the connections 20 b and 20 c ), and the connection 20 a , remain sufficiently tight so as to render the tubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through the tubular string 16 , holding pressure within the tubular string 16 , providing structural support to the wellbore 18 , one or more other intended purposes, or any combination thereof).
- the tubular member, to which the tool 14 is adapted to be connected may not be a casing hanger; instead of the casing hanger 12 , the tool 14 may be connected to another type of hanger, or another tubular member, in a manner similar to the manner in which the tool 14 is connected to the casing hanger 12 .
- the tubular member substituted for the casing hanger 12 , as well as the tool 14 may be positioned anywhere along the tubular string 16 , and may be characterized as part of the tubular string 16 .
- the tool 14 is operable to, for example, convey fluids through the tubular string 16 , hold pressure within the tubular string 16 , provide structural support to the wellbore 18 , or any combination thereof.
- the tubular member substituted for the casing hanger 12 may be positioned inline between the tubular string 16 and another tubular string, or may define a portion of the tubular string 16 upstream of the tool 14 and another portion of the tubular string 16 downstream of the tubular member substituted for the casing hanger 12 .
- the tool 14 is operable to, for example, convey fluids through the tubular string 16 , hold pressure within the tubular string 16 , provide structural support to the wellbore 18 , or any combination thereof.
- the tool 14 enables a customer to rotate the tubular string 16 while installing it in the wellbore 18 . This helps to reduce the risk of the tubular string 16 (such as casing string) getting stuck during installation. This also allows the customer to install the tubular string 16 (such as casing string) into long horizontal wellbore sections.
- the connection between the tool 14 and the casing hanger 12 is the lowest torqued connection in the entire tubular string 16 .
- the tool 14 When, for example, a left hand torque is applied to the entire tubular string 16 , the tool 14 will start to back off from the casing hanger 12 and allow for the tool 14 to be removed from the wellbore 18 .
- the operation of the apparatus 10 including the rotation of the tubular string 16 , does not increase the amount of torque retained in the respective connections between adjacent tubulars in the tubular string 16 .
- disconnecting the tool 14 from the casing hanger 12 (or from another tubular member) does not increase the risk of breaking any of the respective connections between adjacent tubulars in the tubular string 16 .
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Abstract
In one aspect, a system includes a tool, a hanger connected to the tool, and a plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore. The tool, hanger, and tubulars are rotatable in response to at least the application of torsion to the tool, and without transferring torque to the connection between the tool and the hanger. In another aspect, a method includes positioning a tubular string within a wellbore, connecting a hanger to the tubular string, and applying torsion to the tubular string to rotate the tubular string. To apply torsion to rotate, a tool is connected to the hanger, and torsion is applied to the tool without transferring torque to the connection between the tool and the hanger. In another aspect, there is provided an apparatus for rotating a tubular string in a preexisting structure, such as a wellbore.
Description
- This application is a continuation of U.S. patent application Ser. No. 15/464,893, filed Mar. 31, 2017, which is a continuation of U.S. patent application Ser. No. 14/250,111, filed Apr. 10, 2014, which claims the benefit of the filing date of, and priority to, U.S. patent application No. 61/811,523, filed Apr. 12, 2013, the entire disclosures of which are hereby incorporated herein by reference.
- This disclosure relates in general to a tubular string such as casing string, and in particular to a system and method for rotating casing string.
- In the oil and gas industry, advances in horizontal drilling have allowed drillers to drill extended reach horizontal sections of wellbores. In some cases, during the installation of a casing string into such an extended reach horizontal section, the casing string needs to be rotated to allow the casing string to be installed to the desired depth. However, rotating the casing string sometimes requires the application of torsion to the casing string using a tool. Such an application of torsion may increase the amount of torque retained in one or more connections between different components of the casing installation system. Additionally, after the torsion has been applied, attempting to disconnect the tool from the casing installation system may increase the risk of breaking connections between tubulars in the casing string. Therefore, what is needed is a system, apparatus or method that addresses one or more of the foregoing issues, or one or more other issues.
- In a first aspect, there is provided a system that includes a tool, a hanger connected to the tool, and a plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore that traverses a subterranean formation. Each of the tubulars is connected to at least one other tubular. The tool, the hanger, and the plurality of tubulars, are rotatable in response to at least the application of torsion to the tool. The tool, the hanger, and the plurality of tubulars, are rotatable without transferring torque to the connection between the tool and the hanger.
- In an exemplary embodiment, the hanger is a casing hanger, and the plurality of tubulars is a casing string.
- In another exemplary embodiment, the tool, the hanger, and the plurality of tubulars, rotate in response to at least: the application of a tensile load across the tool; and the application of torsion to the tool during the application of the tensile load across the tool.
- In certain exemplary embodiments, any trapped torsion between any of the respective connections between any two of the tubulars in the plurality of tubulars is released in response to the application of a compressive load across the tool.
- In an exemplary embodiment, after the application of torsion to the tool, the connection between the tool and the hanger is capable of being broken without breaking any of the respective connections between any two of the tubulars in the plurality of tubulars.
- In a second aspect, there is provided a method that includes positioning a tubular string within a wellbore that traverses a subterranean formation, the tubular string including a plurality of tubulars, each of the tubulars being connected to at least one other tubular. A hanger is connected to the tubular string. Torsion is applied to the tubular string to rotate the tubular string. To apply torsion to rotate the tubular string, a tool is connected to the hanger, and torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, without transferring torque to the connection between the tool and the hanger.
- In an exemplary embodiment, the tubular string is a casing string, and the hanger is a casing hanger.
- In another exemplary embodiment, the tool includes a tubular member, and connecting the tool to the hanger includes connecting the tubular member to the hanger. Torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, without transferring torque to the connection between the tubular member and the hanger.
- In certain exemplary embodiments, the method includes applying a compressive load across the tool to release any trapped torsion between any of the respective connections between any two of the tubulars in the tubular string.
- In an exemplary embodiment, the method includes breaking the connection between the tool and the hanger without breaking any of the respective connections between any two of the tubulars in the tubular string.
- In another exemplary embodiment, applying torsion to the tubular string further includes applying a tensile load across the tool. Torsion is applied to the tool, in order to apply torsion to the hanger and thus to the tubular string, during applying the tensile load across the tool.
- In a third aspect, there is provided an apparatus for rotating a tubular string within a preexisting structure. The apparatus includes a first tubular member, a second tubular member extending within the first tubular member, a third tubular member extending within the first tubular member. The apparatus includes a first configuration in which: the third tubular member is in a first position relative to each of the first and second tubular members; torque is permitted to be transmitted between the second and third tubular members to connect the apparatus to, or disconnect the apparatus from, a fourth tubular member adapted to be connected to the tubular string; and torque is not permitted to be transmitted between the first and third tubular members. The apparatus includes a second configuration in which: the third tubular member is in a second position relative to each of the first and second tubular members; torque is not permitted to be transmitted between the second and third tubular members; and torque is permitted be transmitted between the first and third tubular members to rotate the tubular string.
- In an exemplary embodiment, the preexisting structure is a wellbore that traverses a subterranean formation, the fourth tubular member is a casing hanger, and the tubular string is a casing string.
- In another exemplary embodiment, the apparatus includes a torsion nut connected to the first tubular member, and the third tubular member extends through the torsion nut. When the apparatus is in the second configuration, torque is permitted to be transmitted between the first and third tubular members via at least the torsion nut.
- In certain exemplary embodiments, the third tubular member includes a first plurality of keys or slots, and a second plurality of keys or slots axially spaced from the first plurality of keys or slots.
- In an exemplary embodiment, the second tubular member includes a third plurality of keys or slots for complementary engagement with the first plurality of keys or slots when the apparatus is in the first configuration. The torsion nut includes a fourth plurality of keys or slots for complementary engagement with the second plurality of keys or slots when the apparatus is in the second configuration.
- In another exemplary embodiment, the apparatus includes a torsion nut connected to one end of the first tubular member, wherein the third tubular member extends through the torsion nut. The first tubular member includes a fifth plurality of keys or slots at the other end thereof for transmitting torque to the tubular string to rotate the tubular string.
- In certain exemplary embodiments, the apparatus includes the fourth tubular member, the fourth tubular member including a sixth plurality of keys or slots adapted to complementarily engage the fifth plurality of keys or slots of the first tubular member. When the fourth tubular member is connected to the tubular string, torque is adapted to be transmitted to the tubular string via the fourth tubular member.
- In an exemplary embodiment, the apparatus includes a first annular groove formed in the outside surface of the third tubular member, wherein the first annular groove is generally aligned with an end of the torsion nut when the apparatus is in the first configuration, and a second annular groove formed in the outside surface of the third tubular member and axially spaced from the first annular groove, wherein the second annular groove is generally aligned with the end of the torsion nut when the apparatus is in the second configuration.
- In another exemplary embodiment, the first and second tubular members include internal and external shoulders, respectively. The apparatus further includes an annular support that is sandwiched between the external shoulder of the second tubular member and the internal shoulder of the first tubular member when the apparatus is in the first configuration.
- Other aspects, features, and advantages will become apparent from the following detailed description when taken in conjunction with the accompanying drawings, which are a part of this disclosure and which illustrate, by way of example, principles of the inventions disclosed.
- The accompanying drawings facilitate an understanding of the various embodiments.
-
FIG. 1 is a diagrammatic view of an apparatus according to an exemplary embodiment, the apparatus including a tool, a casing hanger and a tubular string. -
FIG. 2 is an exploded perspective view of the tool and the casing hanger ofFIG. 1 , according to an exemplary embodiment. -
FIG. 3 is a sectional view of the tool and the casing hanger ofFIGS. 1 and 2 , according to an exemplary embodiment. -
FIG. 4 is a view similar to that ofFIG. 3 , but depicts the tool in another configuration, according to an exemplary embodiment. -
FIG. 5 is a view similar to that of each ofFIGS. 3 and 4 , but depicts the tool in yet another configuration, according to an exemplary embodiment. - In an exemplary embodiment, as illustrated in
FIG. 1 , an apparatus is generally referred to by thereference numeral 10 and includes a hanger, such as acasing hanger 12, to which atool 14 is connected. Atubular string 16 is connected to thecasing hanger 12, and is positioned within a preexisting structure such as, for example, awellbore 18 that traverses one or more subterranean formations. In an exemplary embodiment, thetubular string 16 is a casing string, which extends within thewellbore 18 to facilitate oil and gas exploration and production operations. Thetubular string 16 includes a plurality of tubulars, each of which is connected to at least one other tubular in thetubular string 16. For example, as shown inFIG. 1 , the plurality of tubulars in thetubular string 16 includes at leasttubulars tubular 16 a is connected to thecasing hanger 12 to define aconnection 20 a, the tubular 16 b is connected to thetubular 16 a to define aconnection 20 b, and the tubular 16 c is connected to the tubular 16 b to define aconnection 20 c. In an exemplary embodiment, each of theconnections tubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through thetubular string 16, holding pressure within thetubular string 16, providing structural support to thewellbore 18, one or more other intended purposes, or any combination thereof). In an exemplary embodiment, each of theconnections tubular string 16 sufficiently operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through thetubular string 16, holding pressure within thetubular string 16, providing structural support to thewellbore 18, one or more other intended purposes, or any combination thereof). - In an exemplary embodiment, as illustrated in
FIG. 2 with continuing reference toFIG. 1 , thetool 14 includes a first tubular member, such as an outer torsion sleeve (or outer sleeve 22), a second tubular member, such as a casing hanger/running tool connection sleeve (or inner sleeve 24), a third tubular member, such as a landing tool/running tool pup (or pup 26), and atorsion nut 28. Thetool 14 further includes anannular support 30, a plurality oftorsion keys 32, a plurality oftorsion keys 34, and a plurality oftorsion keys 36. In an exemplary embodiment, theannular support 30 is a bushing. In an exemplary embodiment, theannular support 30 is a high-capacity axial bearing assembly. - In an exemplary embodiment, as illustrated in
FIGS. 2 and 3 with continuing reference toFIG. 1 , theouter sleeve 22 includes a plurality ofopenings 22 a formed in the bottom end thereof; respective internal threaded connections are formed in theopenings 22 a. Thetorsion keys 32 include respective external threaded connections, which threadably engage with the internal threaded connections in therespective openings 22 a, thereby connecting thetorsion keys 32 to theouter sleeve 22. In an exemplary embodiment, thetorsion keys 32 are connected to theouter sleeve 22 using fasteners, or are integrally formed with theouter sleeve 22. Theouter sleeve 22 further includes an internal threadedconnection 22 b at the end portion thereof opposing theopenings 22 a, and aninternal shoulder 22 c positioned axially between theopenings 22 a and the internal threadedconnection 22 b. - As shown in
FIGS. 2 and 3 , and under conditions to be described below, theouter sleeve 22 is adapted to engage thecasing hanger 12 so that thetorsion keys 32 extend intorespective openings 12 a formed in anexternal shoulder 12 b (seeFIG. 2 ) of thecasing hanger 12, and so that anupper end portion 12 c of thecasing hanger 12 extends within theouter sleeve 22. Aninternal shoulder 12 d, and an internal threadedconnection 12 e adjacent thereto, are formed in theupper end portion 12 c of thecasing hanger 12. Thecasing hanger 12 further includes aflange 12 f, which is adapted to engage a wellhead housing (not shown), under conditions to be described below. - The
inner sleeve 24 extends within theouter sleeve 22, and includes an external threadedconnection 24 a at the lower end thereof, anexternal shoulder 24 b adjacent the external threadedconnection 24 a, and anexternal shoulder 24 c above theexternal shoulder 24 b. Under conditions to be described below, the external threadedconnection 24 a is adapted to threadably engage, and threadably disengage from, the internal threadedconnection 12 e of thecasing hanger 12. Similarly, theexternal shoulder 24 b is adapted to engage, and disengage from, theinternal shoulder 12 d of thecasing hanger 12, and theexternal shoulder 24 c is adapted to engage, and disengage from, theannular support 30. Thetorsion keys 34 are positioned proximate theexternal shoulder 24 c, and are circumferentially spaced around, and connected to, theinner sleeve 24. In an exemplary embodiment, thetorsion keys 34 are connected to theinner sleeve 24 viafasteners 38, which extend radially inwardly into theinner sleeve 24. In an exemplary embodiment, thetorsion keys 34 are connected to theinner sleeve 24 via other types of fasteners, or are integrally formed with theinner sleeve 24. - The
pup 26 extends within theouter sleeve 22, and includesslots 26 a formed in the lower end thereof, aninternal shoulder 26 b, and anexternal shoulder 26 c. Axially-spacedannular grooves pup 26 proximate the upper end portion thereof. Thetorsion keys 36 are positioned adjacent theexternal shoulder 26 c, and are circumferentially spaced around, and connected to, thepup 26. In an exemplary embodiment, thetorsion keys 36 are connected to thepup 26 viafasteners 40, which extend radially inwardly into thepup 26. In an exemplary embodiment, thetorsion keys 36 are connected to thepup 26 via other types of fasteners, or are integrally formed with thepup 26. Thepup 26 extends through thetorsion nut 28, which includes an external threadedconnection 28 a, which is threadably engaged with the internal threadedconnection 22 b of theouter sleeve 22, thereby connecting thetorsion nut 28 to theouter sleeve 22. Thetorsion nut 28 further includes aflange 28 b, which engages the upper end of theouter sleeve 22.Slots 28 c are formed in the lower end of thetorsion nut 28. In several exemplary embodiments, as indicated inFIGS. 2 and 3 , thetool 14 may include annular sealing elements, such as o-rings, which are axially-spaced from one another along thetool 14 and sealingly engage components thereof. - In operation, in an exemplary embodiment, with continuing reference to
FIGS. 1, 2 and 3 , theapparatus 10 facilitates oil and gas exploration and production operations. More particularly, theflange 12 f of thecasing hanger 12 engages a wellhead housing (not shown), and thetubular string 16 hangs from thecasing hanger 12, being positioned within thewellbore 18. In an exemplary embodiment, each of theconnections tubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through thetubular string 16, holding pressure within thetubular string 16, providing structural support to thewellbore 18, one or more other intended purposes, or any combination thereof). In an exemplary embodiment, thetubular string 16 is in tension at least in part because it hangs from thecasing hanger 12. Thecasing hanger 12 suspends thetubular string 16 within thewellbore 18, thereby causing thetubular string 16 to be in tension. In several exemplary embodiments, at any time during the operation of theapparatus 10, thetool 14 may or may not be connected to thecasing hanger 12. - During operation, in several exemplary embodiments, it is desired to rotate the
tubular string 16 about its longitudinal axis while thetubular string 16 is in tension and positioned within thewellbore 18. The rotation of thetubular string 16 may be desirable in order to, for example, allow thetubular string 16 to be installed to the desired depth in the subterranean formation(s) through which thewellbore 18 extends. To so rotate thetubular string 16, thetool 14 is connected to thecasing hanger 12. - To connect the
tool 14 to thecasing hanger 12, thetool 14 is assembled in accordance with the foregoing, and then is moved downwards, as viewed inFIG. 3 . As a result, theupper end portion 12 c of thecasing hanger 12 extends within theouter sleeve 22, as shown inFIG. 3 . Theinner sleeve 24 is moved downward within theouter sleeve 22, as viewed inFIG. 3 , so that the external threadedconnection 24 a may be threadably engaged with the internal threadedconnection 12 e of thecasing hanger 12. Theinner sleeve 24 may be so moved by moving thepup 26 downward, as viewed inFIG. 3 , so that thetorsion keys 34 extend into therespective slots 26 a of thepup 26. Thepup 26 may be rotated, which rotation, due to the extension of thetorsion keys 34 into therespective slots 26 a, transmits torque from thepup 26 to theinner sleeve 24, causing theinner sleeve 24 to rotate and thus the external threadedconnection 24 a to be threadably engaged with the internal threadedconnection 12 e, thereby connecting theinner sleeve 24 to thecasing hanger 12. Theinner sleeve 24 continues to be rotated until theinner sleeve 24 is sufficiently connected to thecasing hanger 12, thereby connecting thetool 14 to thecasing hanger 12. At this point, theouter sleeve 22 engages thecasing hanger 12 so that thetorsion keys 32 complementarily engage, and fully extend into, therespective openings 12 a of thecasing hanger 12. Further, theexternal shoulders internal shoulder 12 d and theannular support 30, respectively. Still further, theannular support 30 is sandwiched between theexternal shoulder 24 c of theinner sleeve 24 and theinternal shoulder 22 c of theouter sleeve 22. Still further, theannular groove 26 e is generally axially aligned with the upper end of thetorsion nut 28, thereby providing an external visual indication that theinner sleeve 24 is sufficiently connected to thecasing hanger 12. In the configuration shown inFIG. 3 , no tensile load is applied across thetool 14. - In an exemplary embodiment, as illustrated in
FIG. 4 with continuing reference toFIGS. 1, 2 and 3 , a tensile load is applied across thetool 14. More particularly, thepup 26 is forced to move upwards, relative to theouter sleeve 22, theinner sleeve 24 and thetorsion nut 28, until thetorsion keys 36 complementarily engage, and fully extend into, therespective slots 28 c of thetorsion nut 28, as shown inFIG. 4 . Thus, thepup 26 shoulders out when thetorsion keys 36 are keyed into therespective slots 28 c. As shown inFIG. 4 , theannular groove 26 d is generally axially aligned with the upper end of thetorsion nut 28, thereby providing an external visual indication that thepup 26 has shouldered out against thetorsion nut 28, and thus a tensile load is being applied across thetool 14. - The tensile load of the
tubular string 16 is transferred from the suspendedtubular string 16 to thecasing hanger 12 via theconnection 20 a (seeFIG. 1 ), from thecasing hanger 12 to theinner sleeve 24 via the threaded engagement between the external threadedconnection 24 a and the internal threadedconnection 12 e, from theinner sleeve 24 to theouter sleeve 22 via the respective engagements between theexternal shoulder 24 c and theannular support 30, and between theinternal shoulder 22 c and theannular support 30, from theouter sleeve 22 to thetorsion nut 28 via the threaded engagement between the external threadedconnection 28 a and the internal threadedconnection 22 b, and from thetorsion nut 28 to thepup 26 via the shouldering out of thepup 26 against thetorsion nut 28. In the configuration shown inFIG. 4 , the tensile load of thetubular string 16 is applied across thetool 14; as a result, theapparatus 10 is in tension while thetubular string 16 is positioned within thewellbore 18. - After applying the tensile load of the
tubular string 16 across thetool 14, torsion is applied to thetubular string 16, while thetubular string 16 is in tension and positioned within thewellbore 18, in order to rotate thetubular string 16 within thewellbore 16. More particularly, when theapparatus 10 is in the configuration shown inFIG. 4 and tension is applied across thetool 14, thepup 16 is rotated about its longitudinal axis, thereby applying torsion to thetool 14. The applied torsion is transmitted from thepup 26 to thetorsion nut 28 via extension of thetorsion keys 36 into therespective slots 28 c, from thetorsion nut 28 to theouter sleeve 22 via the threaded engagement between the external threadedconnection 28 a and the internal threadedconnection 22 b, from theouter sleeve 22 to thecasing hanger 12 via the extension of thetorsion keys 32 into therespective openings 12 a, from thecasing hanger 12 to the tubular 16 a via theconnection 20 a (seeFIG. 1 ), from the tubular 16 a to the tubular 16 b via theconnection 20 b (seeFIG. 1 ), from the tubular 16 b to the tubular 16 c via theconnection 20 c (seeFIG. 1 ), etc. In response to this applied torsion, thetubular string 16 rotates about its longitudinal axis within thewellbore 18 while remaining in tension. The applied torsion is not transmitted or transferred to the connection between thetool 14 and thecasing hanger 12, that is, the threaded engagement between the external threadedconnection 24 a and the internal threadedconnection 12 e. - In several exemplary embodiments, so long as tension is applied across the
tool 14 while thetool 14 is connected to thecasing hanger 12, thetool 14 is capable of carrying the tensile load of, and rotating, thetubular string 16, without transferring torque to the connection between thetool 14 and thecasing hanger 12, that is, the threaded engagement between the external threadedconnection 24 a of theinner sleeve 24 and the internal threadedconnection 12 e of thecasing hanger 12. Thus, the amount of torque necessary to disconnect the inner sleeve 24 (and thus the tool 14) from thecasing hanger 12 is not increased as a result of applying torsion to thetool 14, thecasing hanger 12 and thetubular string 16. - In an exemplary embodiment, when a compressive load is applied across the
tool 14, thepup 26 moves downward, as viewed inFIGS. 3 and 4 , and un-keys from thetorsion nut 28. That is, thetorsion keys 36 no longer extend into therespective slots 28 c, as shown inFIG. 3 . As a result, any trapped torsion between any two of the tubulars (e.g., thetubulars tubulars tubular string 16 is released. Moreover, any trapped torsion between any two of the above-described pairs of components used to transmit or transfer torque from thepup 16 to the tubular 16 c is released. For example, any trapped torsion in any of theconnections tool 14 by forcing thepup 26 to move downward, as viewed inFIG. 3 . In an exemplary embodiment, a compressive load may be applied across thetool 14 by permitting theapparatus 10 to be dropped into, or landed in, the wellhead profile, and/or manipulating theapparatus 10 or components thereof so that theapparatus 10 drops into, or lands in, the wellhead profile. Thepup 26 continues to move downward until it keys into theinner sleeve 24, that is, thetorsion keys 34 complementarily engage, and fully extend into, therespective slots 26 a of thepup 26, as shown inFIG. 3 . - In an exemplary embodiment, as illustrated in
FIG. 5 with continuing reference toFIGS. 1, 2, 3 and 4 , after thepup 26 has keyed into theinner sleeve 24, thetool 14 may be disconnected from thecasing hanger 12. To disconnect thetool 14 from thecasing hanger 12, thepup 26 is rotated, which rotation, due to the extension of thetorsion keys 34 into therespective slots 26 a, transmits torque from thepup 26 to theinner sleeve 24, causing theinner sleeve 24 to rotate and thus break the connection between thetool 14 and thecasing hanger 12, that is, the threaded engagement between the external threadedconnection 24 a and the internal threadedconnection 12 e. Accordingly, continued rotation of thepup 26 causes the external threadedconnection 24 a to be threadably disengaged from the internal threadedconnection 12 e. As a result, thetool 14 is disconnected from thecasing hanger 12. During or after the rotation effecting this disconnection, thepup 26 may be forced upwards until theannular groove 26 d is generally axially aligned with the upper end of thetorsion nut 28, thereby providing an external visual indication that theinner sleeve 24, and thus thetool 14, is fully disconnected from thecasing hanger 12. This external visual indication is shown inFIG. 5 . Since thetool 14 is disconnected from thecasing hanger 12, thetool 14 may be lifted off of thecasing hanger 12 so that that thetorsion keys 32 no longer extend into therespective openings 12 a of thecasing hanger 12. - During the above-described disconnection of the
tool 14 from thecasing hanger 12, the connection between thetool 14 and thecasing hanger 12 may be broken without breaking theconnection 20 a (seeFIG. 1 ), and without breaking any of the respective connections between any two of the tubulars in thetubular string 16, such as theconnection FIG. 1 ). This is possible because thetool 14 permitted torsion to be applied to thetubular string 16, in order to rotate thetubular string 16 within thewellbore 18 as described above, without transferring torque to the connection between thetool 14 and thecasing hanger 12. In several exemplary embodiments, use of thetool 14 to rotate thetubular string 16 eliminates, or at least reduces, the risk that theconnection tubular string 16, may be broken before the connection between thetool 14 and thecasing hanger 12 is broken. As a result, all connections between the tubulars in the tubular string 16 (including theconnections connection 20 a, remain sufficiently tight so as to render thetubular string 16 operable for its intended purposes within the wellbore 18 (e.g., conveying fluids through thetubular string 16, holding pressure within thetubular string 16, providing structural support to thewellbore 18, one or more other intended purposes, or any combination thereof). - In several exemplary embodiments, the tubular member, to which the
tool 14 is adapted to be connected, may not be a casing hanger; instead of thecasing hanger 12, thetool 14 may be connected to another type of hanger, or another tubular member, in a manner similar to the manner in which thetool 14 is connected to thecasing hanger 12. In several exemplary embodiments, the tubular member substituted for thecasing hanger 12, as well as thetool 14, may be positioned anywhere along thetubular string 16, and may be characterized as part of thetubular string 16. Since thetool 14 is part of thetubular string 16, thetool 14 is operable to, for example, convey fluids through thetubular string 16, hold pressure within thetubular string 16, provide structural support to thewellbore 18, or any combination thereof. Alternatively, in several exemplary embodiments, the tubular member substituted for thecasing hanger 12, as well as thetool 14, may be positioned inline between thetubular string 16 and another tubular string, or may define a portion of thetubular string 16 upstream of thetool 14 and another portion of thetubular string 16 downstream of the tubular member substituted for thecasing hanger 12. Since thetool 14 is positioned inline between thetubular string 16 and another tubular string, or defines upstream and downstream portions of thetubular string 16, thetool 14 is operable to, for example, convey fluids through thetubular string 16, hold pressure within thetubular string 16, provide structural support to thewellbore 18, or any combination thereof. - In several exemplary embodiments, the
tool 14 enables a customer to rotate thetubular string 16 while installing it in thewellbore 18. This helps to reduce the risk of the tubular string 16 (such as casing string) getting stuck during installation. This also allows the customer to install the tubular string 16 (such as casing string) into long horizontal wellbore sections. In several exemplary embodiments, after the mandrel casing hanger has been landed in the wellhead profile and thetool 14 is in compression, the connection between thetool 14 and thecasing hanger 12 is the lowest torqued connection in the entiretubular string 16. When, for example, a left hand torque is applied to the entiretubular string 16, thetool 14 will start to back off from thecasing hanger 12 and allow for thetool 14 to be removed from thewellbore 18. In several exemplary embodiments, the operation of theapparatus 10, including the rotation of thetubular string 16, does not increase the amount of torque retained in the respective connections between adjacent tubulars in thetubular string 16. Moreover, in several exemplary embodiments, disconnecting thetool 14 from the casing hanger 12 (or from another tubular member) does not increase the risk of breaking any of the respective connections between adjacent tubulars in thetubular string 16. - In the foregoing description of certain embodiments, specific terminology has been resorted to for the sake of clarity. However, the disclosure is not intended to be limited to the specific terms so selected, and it is to be understood that each specific term includes other technical equivalents which operate in a similar manner to accomplish a similar technical purpose. Terms such as “left” and right”, “front” and “rear”, “above” and “below” and the like are used as words of convenience to provide reference points and are not to be construed as limiting terms.
- In this specification, the word “comprising” is to be understood in its “open” sense, that is, in the sense of “including”, and thus not limited to its “closed” sense, that is the sense of “consisting only of”. A corresponding meaning is to be attributed to the corresponding words “comprise”, “comprised” and “comprises” where they appear.
- In addition, the foregoing describes only some embodiments of the invention(s), and alterations, modifications, additions and/or changes can be made thereto without departing from the scope and spirit of the disclosed embodiments, the embodiments being illustrative and not restrictive.
- Furthermore, invention(s) have described in connection with what are presently considered to be the most practical and preferred embodiments, it is to be understood that the invention is not to be limited to the disclosed embodiments, but on the contrary, is intended to cover various modifications and equivalent arrangements included within the spirit and scope of the invention(s). Also, the various embodiments described above may be implemented in conjunction with other embodiments, e.g., aspects of one embodiment may be combined with aspects of another embodiment to realize yet other embodiments. Further, each independent feature or component of any given assembly may constitute an additional embodiment.
Claims (20)
1. An apparatus adapted to be associated with an oil and gas wellbore, the apparatus comprising:
a first tubular member;
a second tubular member extending within the first tubular member;
a torsion nut connected to the first tubular member; and
a third tubular member extending through the torsion nut and within the first tubular member;
wherein the third tubular member is engageable with the second tubular member to transmit torque therebetween; and
wherein the third tubular member is engageable with the torsion nut to transmit torque therebetween.
2. The apparatus of claim 1 , wherein the second tubular member comprises a first plurality of keys or slots; and wherein the third tubular member comprises a second plurality of keys or slots.
3. The apparatus of claim 2 , wherein the third tubular member further comprises a third plurality of keys or slots axially spaced from the second plurality of keys or slots; and
wherein the torsion nut comprises a fourth plurality of keys or slots.
4. The apparatus of claim 3 , wherein the third tubular member is moveable, within the first tubular member, between:
a first position in which the second plurality of keys or slots of the third tubular member are complementarily engaged with the first plurality of keys or slots of the second tubular member so that torque is permitted to be transmitted between the third and second tubular members; and
a second position in which the third plurality of keys or slots of the third tubular member are complementarily engaged with the fourth plurality of keys or slots of the torsion nut so that torque is permitted to be transmitted between the third tubular member and the torsion nut.
5. The apparatus of claim 4 , further comprising a first indicator associated with the third tubular member and configured to indicate that the third tubular member is in the first position.
6. The apparatus of claim 5 , further comprising a second indicator associated with the third tubular member and configured to indicate that the third tubular member is in the second position.
7. The apparatus of claim 6 , wherein the first indicator comprises a first annular groove formed in an outside surface of the third tubular member;
wherein the first annular groove is generally aligned with an end of the torsion nut when the third tubular member is in the first position;
wherein the second indicator comprises a second annular groove formed in the outside surface of the third tubular member and axially spaced from the first annular groove; and
wherein the second annular groove is generally aligned with the end of the torsion nut when the third tubular member is in the second position.
8. The apparatus of claim 1 , wherein the third tubular member is moveable, within the first tubular member, between:
a first position in which the third tubular member is engaged with the second tubular member so that torque is permitted to be transmitted between the third and second tubular members;
and
a second position in which the third tubular member is engaged with the torsion nut so that torque is permitted to be transmitted between the third tubular member and the torsion nut.
9. The apparatus of claim 8 , further comprising a first indicator associated with the third tubular member and configured to indicate that the third tubular member is in the first position.
10. The apparatus of claim 9 , further comprising a second indicator associated with the third tubular member and configured to indicate that the third tubular member is in the second position.
11. The apparatus of claim 10 , wherein the first indicator comprises a first annular groove formed in an outside surface of the third tubular member;
wherein the first annular groove is generally aligned with an end of the torsion nut when the third tubular member is in the first position;
wherein the second indicator comprises a second annular groove formed in the outside surface of the third tubular member and axially spaced from the first annular groove; and
wherein the second annular groove is generally aligned with an end of the torsion nut when the third tubular member is in the second position.
12. The apparatus of claim 1 , further comprising a plurality of keys connected to the first tubular member at one end thereof.
13. The apparatus of claim 12 , wherein the first tubular member comprises openings formed in the one end thereof, and respective internal threaded connections formed in the openings;
wherein the keys comprise respective external threaded connections; and
wherein the keys extend into the openings, respectively, and the respective external threaded connections of the keys are threadably engaged with the respective internal threaded connections of the openings.
14. A method associated with an oil and gas wellbore, the method comprising:
connecting a tool to a component, the tool comprising a first tubular member, a second tubular member extending within the first tubular member, and a third tubular member extending within the first tubular member, the component being connected to a tubular string that extends within the oil and gas wellbore;
wherein connecting the tool to the component comprises:
positioning the third tubular member is in a first position, relative to each of the first and second tubular members; and
when the third tubular member is in the first position, transmitting torque between the third and second tubular members to connect the tool to the component.
15. The method of claim 14 , further comprising:
positioning the third tubular member in a second position, relative to each of the first and second tubular members; and
when the third tubular member is in the second position, transmitting torque between the third and first tubular members.
16. The method of claim 15 , wherein transmitting the torque between the third and first tubular members comprises:
transmitting the torque between the third and first tubular members via at least a torsion nut, which is connected to the first tubular member and through which the third tubular member extends.
17. The method of claim 16 , wherein the third tubular member comprises a first plurality of keys or slots, and the torsion nut comprises a second plurality of keys or slots; and
wherein transmitting the torque between the third and first tubular members via at least the torsion nut comprises complementarily engaging the first plurality of keys or slots of the third tubular member with the second plurality of keys or slots of the torsion nut.
18. The method of claim 15 , further comprising:
disconnecting the tool from the component;
wherein disconnecting the tool from the component comprises:
positioning the third tubular member in the first position, relative to each of the first and second tubular members; and
when the third tubular member is in the first position, transmitting torque between the third and second tubular members to disconnect the tool from the component.
19. The method of claim 14 , wherein the second tubular member and the third tubular member comprise a first plurality of keys or slots and a second plurality of keys or slots, respectively; and
wherein transmitting the torque between the third and second tubular members, to connect the tool to the component, comprises:
complementarily engaging the second plurality of keys or slots of the third tubular member with the first plurality of keys or slots of the second tubular member.
20. The method of claim 14 , further comprising:
positioning the third tubular member in a second position, relative to each of the first and second tubular members; and
when the third tubular member is in the second position, transmitting torque between the component and the tubular string;
wherein transmitting the torque between the component and the tubular string comprises:
transmitting torque between the third and first tubular members; and
transmitting torque between the first tubular member and the component.
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US16/057,185 US20180340400A1 (en) | 2013-04-12 | 2018-08-07 | System and method for rotating casing string |
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US14/250,111 US9605503B2 (en) | 2013-04-12 | 2014-04-10 | System and method for rotating casing string |
US15/464,893 US10087726B2 (en) | 2013-04-12 | 2017-03-21 | System and method for rotating casing string |
US16/057,185 US20180340400A1 (en) | 2013-04-12 | 2018-08-07 | System and method for rotating casing string |
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US15/464,893 Continuation US10087726B2 (en) | 2013-04-12 | 2017-03-21 | System and method for rotating casing string |
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US14/250,111 Active 2035-01-20 US9605503B2 (en) | 2013-04-12 | 2014-04-10 | System and method for rotating casing string |
US15/464,893 Expired - Fee Related US10087726B2 (en) | 2013-04-12 | 2017-03-21 | System and method for rotating casing string |
US16/057,185 Abandoned US20180340400A1 (en) | 2013-04-12 | 2018-08-07 | System and method for rotating casing string |
Family Applications Before (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/250,111 Active 2035-01-20 US9605503B2 (en) | 2013-04-12 | 2014-04-10 | System and method for rotating casing string |
US15/464,893 Expired - Fee Related US10087726B2 (en) | 2013-04-12 | 2017-03-21 | System and method for rotating casing string |
Country Status (2)
Country | Link |
---|---|
US (3) | US9605503B2 (en) |
WO (1) | WO2014169174A1 (en) |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9605503B2 (en) * | 2013-04-12 | 2017-03-28 | Seaboard International, Inc. | System and method for rotating casing string |
CA3003296C (en) | 2015-10-29 | 2022-05-10 | Stream-Flo Industries Ltd. | Running tool locking system and method |
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US9605503B2 (en) * | 2013-04-12 | 2017-03-28 | Seaboard International, Inc. | System and method for rotating casing string |
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- 2014-04-11 WO PCT/US2014/033742 patent/WO2014169174A1/en active Application Filing
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2017
- 2017-03-21 US US15/464,893 patent/US10087726B2/en not_active Expired - Fee Related
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2018
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US9605503B2 (en) * | 2013-04-12 | 2017-03-28 | Seaboard International, Inc. | System and method for rotating casing string |
Also Published As
Publication number | Publication date |
---|---|
US9605503B2 (en) | 2017-03-28 |
WO2014169174A1 (en) | 2014-10-16 |
US10087726B2 (en) | 2018-10-02 |
US20140305659A1 (en) | 2014-10-16 |
US20170191353A1 (en) | 2017-07-06 |
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