US20150135501A1 - Systems and methods for making and breaking threaded joints using orbital motions - Google Patents
Systems and methods for making and breaking threaded joints using orbital motions Download PDFInfo
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- US20150135501A1 US20150135501A1 US14/548,412 US201414548412A US2015135501A1 US 20150135501 A1 US20150135501 A1 US 20150135501A1 US 201414548412 A US201414548412 A US 201414548412A US 2015135501 A1 US2015135501 A1 US 2015135501A1
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- 238000000034 method Methods 0.000 title claims abstract description 87
- 230000033001 locomotion Effects 0.000 title description 15
- 230000001154 acute effect Effects 0.000 claims description 7
- 230000003247 decreasing effect Effects 0.000 claims description 7
- 238000005553 drilling Methods 0.000 description 14
- 230000007423 decrease Effects 0.000 description 10
- 230000001939 inductive effect Effects 0.000 description 7
- 230000013011 mating Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 239000000463 material Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 230000002441 reversible effect Effects 0.000 description 2
- 238000005452 bending Methods 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
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Classifications
-
- 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
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/16—Connecting or disconnecting pipe couplings or 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
- 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
- E21B17/042—Threaded
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T29/00—Metal working
- Y10T29/49—Method of mechanical manufacture
- Y10T29/49815—Disassembling
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T29/00—Metal working
- Y10T29/49—Method of mechanical manufacture
- Y10T29/49826—Assembling or joining
- Y10T29/49947—Assembling or joining by applying separate fastener
- Y10T29/49963—Threaded fastener
Definitions
- the invention relates generally to the makeup and breakup of threaded joints and connections. More particularly, the invention relates to the makeup and breakup of threaded joints in tubular strings used in oil and gas drilling and production operations.
- a variety of conduits, flowlines, and tubular strings used in oil and gas operations are formed threadably connecting tubular members end-to-end.
- a plurality of rigid elongate drill pipe sections are typically threadably connected end-to-end to form a drillstring with a drill bit disposed at the lower end thereof.
- the drill bit is rotated (e.g., by a top drive or a mud motor) about a central axis with weight on bit (“WOB”) applied such that the bit engages the earthen formation to lengthen the borehole.
- WOB weight on bit
- each new pipe section is lowered such that its lower end engages the upper most end of the drillstring and is coaxially aligned with the central axis of the drillstring. Thereafter, the new pipe section is rotated about the central axis of the drillstring such that threads disposed on its lower end engage with corresponding threads on the upper most end of the drillstring.
- a final makeup torque is applied (e.g., by a wrench or other similar tool) to ensure that the connection is fully made up. This process is repeated with new pipe sections being added to the upper end of the drilistring as the drill bit lengthens the borehole until the desired depth is achieved.
- Some embodiments are directed to a method for making a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end.
- the method comprises (a) moving the first tubular axially relative to the second tubular to position the pin-end connector of the first tubular at least partially within the box-end connector of the second tubular, in addition, the method comprises (b) orbiting the pin-end connector of the first tubular about the central axis of the second tubular. Further, the method comprises (c) rotating the first tubular about the central axis of the first tubular in the opposite direction during (b). Still further, the method comprises (d) threading the pin-end connector of the first tubular into the box-end connector of the second tubular during (b) and (c).
- inventions are directed to a method for breaking a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end.
- the method comprises (a) orbiting the pin-end connector of the first tubular about the central axis of the second tubular.
- the method comprises (b) rotating the first tubular about the central axis of the first tubular during (a) in the opposite direction.
- the method comprises (c) unthreading the pin-end connector of the first tubular from the box-end connector of the second tubular during (a) and (b). Still further, the method comprises (d) moving the first tubular axially relative to the second tubular to remove the pin-end connector of the first tubular from the box-end connector of the second tubular.
- Still other embodiments are directed to a method for assembling a tubular string for an oil and gas operation, wherein the tubular string comprises a plurality of elongate threaded tubulars, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector disposed at the first end, and an externally threaded pin-end connector disposed at the second end.
- the method comprises (a) lowering the tubular string into a borehole.
- the method comprises (b) lowering a first tubular axially toward the tubular string to position the pin-end connector of the first tubular into a box-end connector disposed at an upper end of the tubular string. Further, the method comprises (c) orbiting the pin-end connector of the first tubular about the central axis of the tubular string. Still further, the method comprises (d) rotating the first tubular about the central axis of the tubular string during (c). Also, the method comprises (e) threading the pin-end connector of the first tubular into the box end connector of the tubular string during (c) and (d) to lengthen the tubular string.
- Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods.
- the foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood,
- the various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated by those skilled in the art that the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
- FIG. 1 is a schematic view of an embodiment of offshore drilling and/or production system
- FIG. 2 is an enlarged schematic cross-sectional view of a segment of the drillstring of FIG. 1 ;
- FIG. 3 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up the segment of FIG. 2 ;
- FIG. 4 is a schematic cross-sectional view, with the gap between the pin and the box magnified for clarity, taken along section IV-IV of FIG. 3 ;
- FIG. 5 is a schematic cross-sectional view also taken along section IV-IV of FIG. 3 at a different point in time than that shown in FIG. 4 ;
- FIG. 6 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up the segment of FIG. 2 ;
- FIG. 7 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for breaking up the segment of FIG. 2 ;
- FIG. 8 is a schematic cross-sectional view taken along section VIII-VIII of FIG. 7 ;
- FIG. 9 is a schematic cross-sectional view also taken along section VIII-VIII of FIG. 7 taken at a different point in time than that shown in FIG. 8 ;
- FIG. 10 is a schematic cross-sectional view illustrating an embodiment of a method in accordance with the principles described herein for breaking up the segment of FIG. 2 ;
- FIG. 11 is a schematic perspective view illustrating the segment of FIG. 2 undergoing makeup/breakup operations through utilization of an orbit inducing engagement device in accordance with the principles disclosed herein;
- FIG. 12 is a schematic perspective view of the drillstring segment of FIG. 2 undergoing makeup/breakup operations through utilization of the orbit inducing engagement device of FIG. 11 ;
- FIG. 13 is a graphical illustration of a method in accordance with the principles disclosed herein for assembling a tubular string
- FIG. 14 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up a threaded connection between a threaded rod and a nut;
- FIG. 15 is an enlarged schematic cross-sectional view of a segment of the drillstring of FIG. 1 showing a different embodiment.
- the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .”
- the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections.
- the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis.
- embodiments of systems and methods for making and breaking threaded joints using orbital motions are described for use with a plurality of tubular sections making up a drilistring.
- embodiments of the systems and methods described herein may be utilized in wide variety of systems and applications which employ threaded connections to make up adjacent tubular sections while still complying with the principles disclosed herein, such as for example, for production tubing sections and casing pipe sections.
- embodiments of the systems and methods described herein may be utilized to facilitate the makeup of other known threaded connections, such as, for example, a threaded connection between a bolt and nut.
- system 10 includes a floating platform 20 disposed at the sea surface 12 , a subsea blowout preventer (BOP) 25 mounted to a wellhead 34 disposed at the sea floor 13 , and a lower marine riser package (LMRP) 27 mounted to the upper end of BOP 25 .
- a drilling riser 40 extends from platform 20 to LMRP 27 .
- riser 40 is a large-diameter pipe that connects LMRP 27 to the floating platform 20 .
- riser 40 takes mud returns to the platform 20 .
- Casing 31 extends from wellhead 34 into subterranean wellbore 14 .
- Riser 40 has a central axis 45 and includes a first or upper end 40 a coupled to platform 20 and a second or lower end 40 b coupled to LMRP 27 .
- riser 40 is made up of a plurality of elongate riser sections 44 coupled end-to-end at joints 46 .
- joints 46 are threaded joints; however, it should be appreciated that other types of connections are possible, such as, for example, bolted flange connections.
- Drilling operations are carried out by a tubular string or drillstring 50 supported by platform 20 and extending through riser 40 , LMRP 27 , BOP 25 , and into cased wellbore 14 .
- drillstring 50 is made up of a plurality of elongate tubular sections 110 coupled end-to-end at threaded joints 120 .
- An annulus 48 is formed between drillstring 50 and riser 40 .
- a drill bit 32 disposed at the lower end of drillstring 50 is rotated as weight-on-bit (WOB) is applied to drill wellbore 14 .
- drilling fluid e.g., mud
- WOB weight-on-bit
- each section 110 comprises an elongate tubular body 112 having a central, longitudinal axis 125 .
- Each body 112 has a first or upper end 112 a, a second or lower end 112 b, a radially outer surface 112 c extending between ends 112 a, 112 b, and a radially inner surface 112 d extending between ends 112 a, 112 b.
- Inner surface 112 d defines a throughbore 114 extending between ends 112 a, 112 b.
- each upper end 112 a comprises a female box-end connector 116 and each lower end 112 b comprises a male pin-end connector 118 .
- Each box-end connector 116 includes internal threads 117
- each pin-end connector 118 includes external threads 119 .
- Connectors 116 , 118 and threads 117 , 119 are sized and configured to threadably mate and engage to form joint 120 .
- Outer surface 112 c of each body 112 is disposed at an outer diameter D 110o
- inner surface 112 d of each body 112 is disposed at an inner diameter D 110i
- Outer surface 112 c is cylindrical between upper end 112 a and pin-end connector 118 , and is frustoconical along connector 118 .
- outer diameter D 110o is uniform between end 112 a and pin-end connector 118 , but decreases moving axially along pin-end connector 118 toward lower end 112 b.
- Inner surface 112 d is cylindrical between lower end 112 b and box-end connector 116 , and is frustoconical along connector 116 .
- inner diameter D 110i is uniform between end 112 b and box-end connector 116 , but increases moving axially along box-end connector 116 toward lower end 112 a.
- the upper pipe or drillstring section 110 of segment 100 will be referred to as section 110 A
- the lower pipe or drillstring section 110 of segment 100 will be referred to as section 110 B
- axes 125 of sections 110 A, 110 B will be referred to as axes 125 A, 125 B, respectively.
- sections 110 A, 110 B are threadably connected together end-to-end at joint 120 with mating connectors 116 , 118 as shown in FIG. 2
- axes 125 A, 125 B are coaxially aligned and throughbores 114 are aligned to form a continuous flow passage through segment 100 .
- FIGS. 3-5 an embodiment of a method for making up threaded joints 120 between connectors 118 , 116 of sections 110 A, 110 B, respectively, is shown.
- axes 125 A, 125 B are oriented parallel to each other, but radially spaced apart.
- axis USA is offset from axis 125 B (i.e., axes 125 A, 125 B are not coaxially aligned).
- section 110 A is whirled or orbited about axis 125 B of lower section 110 B in direction 127 such that axis 125 A of section 110 A orbits about axis 125 B as pin-end connector 118 rolls inside the box and is threaded into box-end connector 116 to makeup threaded joint 120 .
- the method for making up threaded joint 120 shown in FIG. 3 offers the potential to reduce the input torque required to fully make up joint 120 .
- some embodiments of the method for making up threaded joint 120 in FIG. 3 offer the potential to produce an enhanced residual stress state for joint 120 following makeup.
- outer surface 112 c of section 110 A engages inner surface 112 d of section 110 B such that internal threads 117 on connector 116 of section 110 B engage external threads 119 on connector 118 of section 110 A at a point of contact 130 .
- a torque is generated that is applied to section 110 A (i.e., a torsional force results from the induced orbital motion) and friction arises between sections 110 A, 110 B at point 130 .
- a torque is generated that is applied to section 110 A (i.e., a torsional force results from the induced orbital motion) and friction arises between sections 110 A, 110 B at point 130 .
- Each of the induced torque as well as the resulting friction work to facilitate rotation of section 110 A about its own central axis 125 A.
- the orbit of section 110 A about axis 125 B results in a torque T 130 applied to section 110 A about the center 125 A.
- a frictional force F 130′ acts at point 130 to resist slipping of threads 117 , 119 due to orbit of section 110 A in direction 127 .
- torque T 130 and friction force F 130′ drive the rotation of section 110 A about axis 125 A in a direction 129 .
- Rotation of section 110 A about axis 125 A can be further supplemented by an external device such as a spinner assembly or tongs.
- the orbiting and rotation can be accomplished by any device known in the art, such as by modified tongs with eccentrics, gears, hydraulic cylinders, radial impacts and resonance machines.
- a second frictional force F 130′′ also acts on sections 110 A, 110 B to resist slipping between threads 117 , 119 due to the rotation of section 110 A relative to section 110 B.
- Force F 130′′ is analogous to the friction force that must be overcome during conventional makeup operations. However, as is shown in FIGS. 4 and 5 , force F 130′ and torque T 130 are each operate in the opposite direction as force F 130′′ , and thus, at least partially counteract force F 130′′ . Consequently, the overall or net frictional force directly resisting rotation of section 110 A relative to section 110 B is reduced.
- section 110 A by inducing section 110 A to orbit about axis 125 B of section 110 B during makeup operations, at least a portion of the friction between threads 117 , 119 that resists such operations is reduced, thereby allowing joint 120 to be fully made-up with a reduced amount of input torque (e.g., such as would be applied by an external device).
- axis 125 A is initially radially offset from axis 125 B by a radial distance R 129 , and there is clearance gap X 110A-110B radially positioned between sections 110 A, 110 B diametrically opposite contact point 130 .
- mating threaded connectors 118 , 116 of sections 110 A, 110 B, respectively are tapered, as joint 120 is made-up, axis 125 A moves or translates toward axis 125 B, radial distance R 129 decreases, and clearance gap X 110A-110B decreases.
- joint 120 is made-up axis 125 A spirals inward toward axis 125 B.
- FIG. 6 another embodiment of a method for making up threaded joint 120 between connectors 118 , 116 of sections 110 A, 110 B, respectively, is shown.
- upper section 110 A is canted or angled relative to lower section such that axis 125 A is disposed at an acute angle ⁇ relative to axis 1252 of lower section 1102 during makeup of joint 120 .
- angle ⁇ is preferably greater than 0.1°.
- the angle ⁇ is chosen such that the moment that generate angle ⁇ has a magnitude which is approximately 10% of the connector capacity (In some embodiments, connector capacity refers to the force that generates a bending moment which results in plastic deformation and/or failure of section 110 A).
- end 112 a of section 110 A is driven to orbit about axis 125 B in direction 127 to produce the same or a similar whirl or orbit of lower end 112 b of section 110 A relative to section 110 B as previously described and shown in FIGS. 4 and 5 .
- the rotational path of section 110 A defines a conical shape.
- the method for making up threaded joint 120 shown in FIG. 6 offers the potential to reduce the torque required to fully make up joint 120 .
- torque T 130 and frictional force F 130′ drive the rotation of section 110 A about axis 125 A in direction 129 .
- Rotation of section 110 A about axis 125 A can be supplemented by an external device such as a spinner assembly or tongs.
- second frictional force F 130′′ acts on sections 110 A, 110 B to resist slipping between threads 117 , 119 due to the rotation of section 110 A relative to section 110 B.
- Torque T 130 and Force F 130′′ each operate in the opposite direction as force F 130′′ , and thus, at least partially counteracts force F 130′′ , thereby reducing the total amount of input torque required to fully make up sections 110 A, 110 B.
- FIGS. 7-9 an embodiment of a method for breaking threaded joint 120 between connectors 118 , 116 of exemplary pipe joints or sections 110 A, 110 B, respectively, is shown.
- A is whirled or orbited about axis 125 B of lower section 110 B.
- the method for breakup of threaded joint 120 shown in FIG. 7 offers the potential to reduce the torque required to fully break up joint.
- a torque T 131 is generated that is applied to section 110 A (i.e., a torsional force results from the induced orbital motion) and a force F 131′ act on sections 110 A, 110 B at a contact point 130 to resist slipping of threads 117 and 119 , and thus, facilitate rotation of section 110 A about its own axis 125 A in direction 133 .
- Rotation of section 110 A about axis 125 A can he supplemented by an external device such as a spinner assembly or tongs.
- a second frictional force F 131′′ resists slipping between threads 117 , 119 due to rotation of section 110 A about axis 125 A relative to section 110 B.
- Force F 131′′ is analogous to the friction that resists relative rotation of sections 110 A, 110 B during conventional breakup operations.
- torque T 130 and force F 131′ operate in the opposite direction as force F 130′′ , and thus, at least partially counteract force F 130′′ . Consequently, the overall or net frictional force directly resisting rotation of section 110 A relative to section 110 B is reduced.
- section 110 A by inducing section 110 A to orbit about axis 125 B of section 110 B during breakup operations, at least a portion of the friction between threads 117 , 119 that resists such operations is reduced, thereby allowing joint 120 to be fully broken with a reduced amount of input torque.
- the breakup is the reverse of the makeup.
- FIG. 10 another embodiment of a method for breaking up threaded joint 120 between connectors 118 , 116 of sections 110 A, 110 B, respectively, is shown.
- upper section 110 A is canted or angled relative to lower section such that axis 125 A is disposed at an acute angle ⁇ relative to axis 125 B of lower section 110 B during breakup of joint 120 .
- angle ⁇ is preferably greater than 0.1°.
- end 112 a of section 110 A is driven to rotate about axis 125 B in a direction 133 to produce the same or a similar whirl or orbit of lower end 112 b of section 110 A relative to section 110 B in direction 131 as previously described and shown in FIGS. 8 and 9 .
- the method for breaking up threaded joint 120 shown in FIG. 10 offers the potential to reduce the torque required to fully brake up joint 120 .
- torque T 131 and frictional force F 131 drive the rotation of section 110 A about axis 125 A in direction 139 .
- Rotation of section 110 A about axis 125 A can be supplemented by an external device such as a spinner assembly or tongs.
- second frictional force F 131′′ acts on sections 110 A, 110 B to resist slipping between threads 117 , 119 due to the rotation of section 110 A relative to section 110 B.
- Torque T 131 and force F 131′ are in the opposite direction as force F 131′′ , and thus, at least partially counteract force F 131′′ .
- FIG. 11 an embodiment of a device 200 in accordance with the principals described herein for inducing the orbital motion of upper section 110 A relative to lower section 110 B as described above and shown in FIGS. 3 , 6 , 7 and 10 to makeup and breakup joint 120 is shown.
- lower section 110 B is held/maintained in position, while device 200 grasps upper section 110 A and induces section 110 A to orbit about axis 125 B of section 110 B.
- device 200 can also induce rotation of section 110 A about its own axis 125 A (in addition to inducing the orbital motion about axis 125 B).
- device 200 can be any suitable device known in the art.
- device 200 can comprise a power tong that induces rotation of section 110 A about axis 125 B of section 110 B and/or angularly deflects section 110 A relative to section 110 B such that the axis 125 A is canted or angled relative to the axis 125 B, while also rotating upper end 112 a relative to lower end 112 b of section 110 A.
- device 200 can comprise a motor with an eccentric mass, such that actuation of motor causes a radial rotating shear force and/or being moment at the connection between sections 118 , 116 which further induces orbital motion of axis 125 A of section 110 A about axis 125 B of section 110 B.
- device 200 is an impact wrench or other similarly powered tool that engages with section 110 A and imparts a force thereto which induces orbital motion of axis 125 A of section 110 A about axis 125 B of section 110 B.
- device 200 orients section 110 A parallel to section 110 B to produce the relative motions of the sections 110 A, 110 B as described above and shown in FIGS. 3 and 7 .
- device 200 orients section 110 A parallel to section 110 B to produce the relative motions of the sections 110 A, 110 B as described above and shown in FIGS. 3 and 7 .
- the device e.g., device 200
- angle ⁇ , radial distance R 129 , and clearance gap X 110A-110B steadily decrease from a maximum to zero or a small value
- clearance gap X 110A-110B steadily increase from zero or a small value to a maximum.
- the angle ⁇ does not decrease from a maximum to zero and the angle ⁇ does not increase from zero to a maximum while still complying with the principles disclosed herein.
- upper section 110 A is manipulated and moved relative to a stationary lower section 110 B to makeup and breakup threaded joint 120 .
- lower section 110 B can be manipulated and moved relative to a stationary upper section 110 A (lower section 110 B orbited about axis 125 A of upper section 110 A with section 110 B parallel to section 110 A or with sections 110 A, 110 B skewed or angled relative to each other).
- device 200 is shown grasping and moving lower section 110 B such that it orbits about axis 125 A of stationary upper section 110 A in a direction 227 to makeup threaded joint 120 .
- upper section 110 A rotates about its axis 125 A in direction 129 (e.g., by torque T 130 and/or force F 130′ alone or in combination with some other input force, each as previously described).
- this method offers the potential to reduce the total input torque necessary to makeup joint 120 .
- both sections 110 A, 110 B can be manipulated and moved relative to each other such that they orbit about each other's axis 125 B, 125 A, respectively (lower section 110 B orbited about axis 125 A of upper section 110 A and upper section 110 A orbited about axis 125 B with sections 110 A, 110 B parallel to each other or with sections 110 A, 110 B skewed or angled relative to each other).
- Method 300 begins at block 305 by inserting (i.e., lowering) the tubular string at least partially into a bore hole with the upper end of the tubular string extending upward therefrom.
- the tubular string can be formed from one or more tubular section(s) (e.g., tubular section 110 A or 110 B).
- a new tubular section is lowered until the lower end of the new tubular section axially abuts and engages the upper end of the tubular string.
- the new tubular section is orbited about the central axis of the tubular string at block 315 in the manner previously described above for sections 110 A, 110 B.
- the new tubular section is rotated about its central axis while orbiting about the central axis of the tubular string.
- a threaded joint between new tubular section and the tubular string is madeup in block 325 , thereby lengthening the tubular string.
- the tubular string with the newly incorporated tubular section is lowered further into the borehole in block 330 .
- steps 310 , 315 , 320 , 325 , and 330 are repeated to integrate additional new tubular sections into the tubular string until the string is fully assembled.
- method 300 can be performed in reverse to unthread and remove tubular sections from the tubular string. While making up the orbit drive can be started just when the connection make up torque start to rise rapidly to assist in the torqueing up of the connection. While breaking the orbit motion can be done just at the beginning to assist in the break up.
- systems and methods described herein offer the potential to reduce the total torque necessary to makeup and breakup threaded joints between tubular sections by inducing orbital motion(s) in one or both tubular sections (e.g., sections 110 A, 110 B).
- Reduced torque loads in turn offer the potential to increase the useful life of the tubular sections by reducing damage and/or wear on the mating threads (e.g., threads 117 , 119 ) and outer surfaces (e.g., surface 112 c ) of tubular sections.
- the reduced torque loads also results in a reduced value of the resulting residual stresses which occur within such threaded connections, which thereby guards against subsequent loosening of the joint after makeup.
- a nut 402 is shown threadably engaged with a threaded rod 410 .
- nut 402 is a standard, conventional hexagonal nut but may be any suitable type of bolt known in the art.
- nut 402 has a central axis 405 and includes a first or upper side 402 a, a second or lower side 402 b opposite the upper side 402 a, and a throughbore 404 extending axially between the sides 402 a, 402 b, and further including a set of internal threads (not shown).
- Rod 410 has a central axis 415 , a first end 410 a, a second end 410 b opposite the first end 410 a, and a radially outer surface 410 c extending between the ends 410 a, 410 b.
- a set of external threads are disposed about the surface 410 c and are configured to engage with the internal threads (not shown) disposed within throughbore 404 of nut 402 .
- nut 402 is disposed on rod 410 such that the axis 405 is parallel to the axis 410 .
- axis 405 of nut 402 is orbited about the axis 415 of rod 410 along an orbital path 418 which further results in the rotation of nut 402 about axis 405 along the direction 420 .
- the orbital motion of nut 402 along path 418 operates to rotate the nut 402 around the rod 410 as it rolls without slipping around the rod 410 , and thus reduces the effective amount of friction opposing the engagement between the corresponding threads of nut 402 and rod 410 which therefor reduces the required amount of input torque necessary to threadably engage nut 402 and rod 410 during operations.
- threaded connections 118 , 116 are not tapered as for the nut and threaded rod example while still complying with the principles disclosed herein.
- outer surface 112 c of each body 112 is disposed at an outer diameter D 110o
- inner surface 112 d of each body 112 is disposed at an inner diameter D 110i .
- Outer surface 112 c is cylindrical between upper end 112 a and pin-end connector 118 a , and is cylindrical along connector 118 a.
- outer diameter D 110o is uniform between end 112 a and lower end 112 b.
- Inner surface 112 d is cylindrical between lower end 112 b and box-end connector 116 a , and is cylindrical along connector 116 a .
- inner diameter D 110i is uniform between end 112 b and lower end 112 a.
- axis 125 A is radially offset from axis 125 B by a radial distance R 129 , and there is clearance gap X 110A-110B radially positioned between sections 110 A, 110 B diametrically opposite contact point 130 .
- axis 125 A remains a constant distance from axis 125 B, radial distance R 129 stays constant, and clearance gap X 110A-110B stays constant until the shoulders make contact.
- the orbit radius is reduced as the triangular thread contact surfaces force the pin and box axis together. Rotation stops when the friction between the threads and the shoulder exceed the combine twisting torque and the orbital radial force.
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- Environmental & Geological Engineering (AREA)
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Abstract
A method for making a threaded joint between first and second tubulars, each tubular including a central axis, a first end, a second end, a throughbore extending between the first second ends, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end, the method including: (a) moving the first tubular axially relative to the second tubular to position the pin-end connector of the first tubular at least partially within the box-end connector of the second tubular. In addition, the method includes (b) orbiting the pin-end connector of the first tubular about the central axis of the second tubular; and (c) rotating the first tubular about the central axis of the first tubular during (b). Further, the method includes (d) threading the pin-end connector of the first tubular into the box-end connector of the second tubular dining (b) and (c).
Description
- This application claims benefit of U.S. provisional patent application Ser. No. 61/906,696 filed Nov. 20, 2013, and entitled “Systems and Methods for Making and Breaking Threaded Joints Using Orbital Motions,” which is hereby incorporated herein by reference in its entirety for all purposes.
- Not applicable.
- The invention relates generally to the makeup and breakup of threaded joints and connections. More particularly, the invention relates to the makeup and breakup of threaded joints in tubular strings used in oil and gas drilling and production operations.
- A variety of conduits, flowlines, and tubular strings used in oil and gas operations, such as drillstrings, risers, conductors, tubings and casings, are formed threadably connecting tubular members end-to-end. For example, when drilling an oil and gas well, a plurality of rigid elongate drill pipe sections are typically threadably connected end-to-end to form a drillstring with a drill bit disposed at the lower end thereof. During drilling operations, the drill bit is rotated (e.g., by a top drive or a mud motor) about a central axis with weight on bit (“WOB”) applied such that the bit engages the earthen formation to lengthen the borehole. As the newly formed borehole lengthens, additional pipe sections are threadably connected to the upper most end of the drillstring. Specifically, during such “makeup” operations, each new pipe section is lowered such that its lower end engages the upper most end of the drillstring and is coaxially aligned with the central axis of the drillstring. Thereafter, the new pipe section is rotated about the central axis of the drillstring such that threads disposed on its lower end engage with corresponding threads on the upper most end of the drillstring. Once the new pipe section is threaded onto the drillstring, a final makeup torque is applied (e.g., by a wrench or other similar tool) to ensure that the connection is fully made up. This process is repeated with new pipe sections being added to the upper end of the drilistring as the drill bit lengthens the borehole until the desired depth is achieved.
- To remove the drillstring from the borehole the drillstring is lifted from the borehole as pipe sections at the upper end of the drillstring are de-coupled therefrom. During such “breakup” operations, torque is applied to each threaded connection to rotate each section of drill pipe about the central axis of the drillstring in order to disengage the threaded connection between the drill pipe section and the rest of the drilistring. In this manner the drillstring is disassembled as it is withdrawn from the borehole. During conventional breakup operations, coaxial alignment of each drill pipe section and the rest of the drillstring is substantially maintained as each successive drill pipe section is rotated to de-couple the same from the drillstring.
- During both makeup and breakup operations, frictional forces resist threaded engagement and disengagement, respectively, of the pipe joints being threaded to and unthreaded from, respectively, the drillstring. Relatively large torque loads may be necessary to overcome the frictional forces. However, the application of excessive torque loads can result in damage and/or excessive wear to the pipe joint threads. Further, as the applied torque loads increase, the tools (e.g., wrenches, power tongs, etc.) used to apply torque to the pipe joints can leave gouges and/or scratches to the outer surface of each drill pipe section, potentially decreasing the useful life of the pipe joints.
- Some embodiments are directed to a method for making a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end. In an embodiment, the method comprises (a) moving the first tubular axially relative to the second tubular to position the pin-end connector of the first tubular at least partially within the box-end connector of the second tubular, in addition, the method comprises (b) orbiting the pin-end connector of the first tubular about the central axis of the second tubular. Further, the method comprises (c) rotating the first tubular about the central axis of the first tubular in the opposite direction during (b). Still further, the method comprises (d) threading the pin-end connector of the first tubular into the box-end connector of the second tubular during (b) and (c).
- Other embodiments are directed to a method for breaking a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end. In an embodiment, the method comprises (a) orbiting the pin-end connector of the first tubular about the central axis of the second tubular. In addition, the method comprises (b) rotating the first tubular about the central axis of the first tubular during (a) in the opposite direction. Further, the method comprises (c) unthreading the pin-end connector of the first tubular from the box-end connector of the second tubular during (a) and (b). Still further, the method comprises (d) moving the first tubular axially relative to the second tubular to remove the pin-end connector of the first tubular from the box-end connector of the second tubular.
- Still other embodiments are directed to a method for assembling a tubular string for an oil and gas operation, wherein the tubular string comprises a plurality of elongate threaded tubulars, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector disposed at the first end, and an externally threaded pin-end connector disposed at the second end. In an embodiment, the method comprises (a) lowering the tubular string into a borehole. In addition, the method comprises (b) lowering a first tubular axially toward the tubular string to position the pin-end connector of the first tubular into a box-end connector disposed at an upper end of the tubular string. Further, the method comprises (c) orbiting the pin-end connector of the first tubular about the central axis of the tubular string. Still further, the method comprises (d) rotating the first tubular about the central axis of the tubular string during (c). Also, the method comprises (e) threading the pin-end connector of the first tubular into the box end connector of the tubular string during (c) and (d) to lengthen the tubular string.
- Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods. The foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood, The various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
- For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which
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FIG. 1 is a schematic view of an embodiment of offshore drilling and/or production system; -
FIG. 2 is an enlarged schematic cross-sectional view of a segment of the drillstring ofFIG. 1 ; -
FIG. 3 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up the segment ofFIG. 2 ; -
FIG. 4 is a schematic cross-sectional view, with the gap between the pin and the box magnified for clarity, taken along section IV-IV ofFIG. 3 ; -
FIG. 5 is a schematic cross-sectional view also taken along section IV-IV ofFIG. 3 at a different point in time than that shown inFIG. 4 ; -
FIG. 6 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up the segment ofFIG. 2 ; -
FIG. 7 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for breaking up the segment ofFIG. 2 ; -
FIG. 8 is a schematic cross-sectional view taken along section VIII-VIII ofFIG. 7 ; -
FIG. 9 is a schematic cross-sectional view also taken along section VIII-VIII ofFIG. 7 taken at a different point in time than that shown inFIG. 8 ; -
FIG. 10 is a schematic cross-sectional view illustrating an embodiment of a method in accordance with the principles described herein for breaking up the segment ofFIG. 2 ; -
FIG. 11 is a schematic perspective view illustrating the segment ofFIG. 2 undergoing makeup/breakup operations through utilization of an orbit inducing engagement device in accordance with the principles disclosed herein; -
FIG. 12 is a schematic perspective view of the drillstring segment ofFIG. 2 undergoing makeup/breakup operations through utilization of the orbit inducing engagement device ofFIG. 11 ; -
FIG. 13 is a graphical illustration of a method in accordance with the principles disclosed herein for assembling a tubular string; -
FIG. 14 is a schematic perspective view illustrating an embodiment of a method in accordance with the principles described herein for making up a threaded connection between a threaded rod and a nut; and -
FIG. 15 is an enlarged schematic cross-sectional view of a segment of the drillstring ofFIG. 1 showing a different embodiment. - The following discussion is directed to various exemplary embodiments. However, one skilled in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
- Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
- In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections. In addition, as used herein, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis.
- In the following description and figures, embodiments of systems and methods for making and breaking threaded joints using orbital motions are described for use with a plurality of tubular sections making up a drilistring. However, it should be appreciated that embodiments of the systems and methods described herein may be utilized in wide variety of systems and applications which employ threaded connections to make up adjacent tubular sections while still complying with the principles disclosed herein, such as for example, for production tubing sections and casing pipe sections. In addition, embodiments of the systems and methods described herein may be utilized to facilitate the makeup of other known threaded connections, such as, for example, a threaded connection between a bolt and nut. Therefore, use of embodiments of the systems and methods described herein to facilitate the threaded connection between adjacent drillstring sections is only one of many potential uses thereof. Thus, any reference to drillstrings and related subject matter is merely included to provide context to the description contained herein and is in no way meant to limit the scope thereof.
- Referring now to
FIG. 1 , an embodiment of anoffshore system 10 for drilling and/or producing asubsea well 30 is shown. In this embodiment,system 10 includes a floatingplatform 20 disposed at the sea surface 12, a subsea blowout preventer (BOP) 25 mounted to awellhead 34 disposed at the sea floor 13, and a lower marine riser package (LMRP) 27 mounted to the upper end ofBOP 25. Adrilling riser 40 extends fromplatform 20 to LMRP 27. In general,riser 40 is a large-diameter pipe that connectsLMRP 27 to the floatingplatform 20. During drilling operations,riser 40 takes mud returns to theplatform 20.Casing 31 extends fromwellhead 34 intosubterranean wellbore 14. -
Riser 40 has acentral axis 45 and includes a first orupper end 40 a coupled toplatform 20 and a second or lower end 40 b coupled toLMRP 27. In this embodiment,riser 40 is made up of a plurality ofelongate riser sections 44 coupled end-to-end at joints 46. In some embodiments, joints 46 are threaded joints; however, it should be appreciated that other types of connections are possible, such as, for example, bolted flange connections. Drilling operations are carried out by a tubular string ordrillstring 50 supported byplatform 20 and extending throughriser 40,LMRP 27,BOP 25, and into casedwellbore 14. In this embodiment,drillstring 50 is made up of a plurality of elongatetubular sections 110 coupled end-to-end at threadedjoints 120. Anannulus 48 is formed betweendrillstring 50 andriser 40. - During drilling operations, a
drill bit 32 disposed at the lower end ofdrillstring 50 is rotated as weight-on-bit (WOB) is applied to drillwellbore 14. During this process, drilling fluid (e.g., mud) is pumped fromplatform 20, downdrill string 50, out the face ofdrill bit 32, and back upannulus 48. - Referring now to
FIG. 2 , anexemplary segment 100 ofdrillstring 50 including twoexemplary sections 110 connected with one threaded joint 120 is shown. Eachsection 110 is identical. In particular, eachsection 110 comprises an elongatetubular body 112 having a central, longitudinal axis 125. Eachbody 112 has a first orupper end 112 a, a second orlower end 112 b, a radiallyouter surface 112 c extending betweenends inner surface 112 d extending betweenends Inner surface 112 d defines athroughbore 114 extending betweenends upper end 112 a comprises a female box-end connector 116 and eachlower end 112 b comprises a male pin-end connector 118. Each box-end connector 116 includesinternal threads 117, while each pin-end connector 118 includesexternal threads 119.Connectors threads -
Outer surface 112 c of eachbody 112 is disposed at an outer diameter D110o, andinner surface 112 d of eachbody 112 is disposed at an inner diameter D110i. Outer surface 112 c is cylindrical betweenupper end 112 a and pin-end connector 118, and is frustoconical alongconnector 118. Thus, outer diameter D110o is uniform betweenend 112 a and pin-end connector 118, but decreases moving axially along pin-end connector 118 towardlower end 112 b.Inner surface 112 d is cylindrical betweenlower end 112 b and box-end connector 116, and is frustoconical alongconnector 116. Thus, inner diameter D110i is uniform betweenend 112 b and box-end connector 116, but increases moving axially along box-end connector 116 towardlower end 112 a. - For purposes of clarity and further explanation, the upper pipe or
drillstring section 110 ofsegment 100 will be referred to assection 110A, the lower pipe ordrillstring section 110 ofsegment 100 will be referred to assection 110B, and axes 125 ofsections axes sections mating connectors FIG. 2 , axes 125A, 125B are coaxially aligned andthroughbores 114 are aligned to form a continuous flow passage throughsegment 100. - As previously described, threaded joints between tubulars used in oil and gas operations are conventionally made-up and broke-up with the tubulars coaxially aligned. However, in embodiments described herein, the makeup and breakup of threaded joints between tubulars is performed, at least partially, without the tubulars being coaxially aligned. More specifically, referring now to
FIGS. 3-5 , an embodiment of a method for making up threadedjoints 120 betweenconnectors sections axis 125B (i.e., axes 125A, 125B are not coaxially aligned). Thereafter,section 110A is whirled or orbited aboutaxis 125B oflower section 110B indirection 127 such thataxis 125A ofsection 110A orbits aboutaxis 125B as pin-end connector 118 rolls inside the box and is threaded into box-end connector 116 to makeup threaded joint 120. - The method for making up threaded joint 120 shown in
FIG. 3 offers the potential to reduce the input torque required to fully make up joint 120. In addition, some embodiments of the method for making up threaded joint 120 inFIG. 3 offer the potential to produce an enhanced residual stress state for joint 120 following makeup. In particular, as best shown inFIGS. 4 and 5 , assection 110A is orbited aboutaxis 125B indirection 127,outer surface 112 c ofsection 110A engagesinner surface 112 d ofsection 110B such thatinternal threads 117 onconnector 116 ofsection 110B engageexternal threads 119 onconnector 118 ofsection 110A at a point ofcontact 130. Without being limited to this or any other theory, assection 110A orbits aboutaxis 125B, a torque is generated that is applied tosection 110A (i.e., a torsional force results from the induced orbital motion) and friction arises betweensections point 130. Each of the induced torque as well as the resulting friction work to facilitate rotation ofsection 110A about its owncentral axis 125A. In particular, the orbit ofsection 110A aboutaxis 125B results in a torque T130 applied tosection 110A about thecenter 125A. In addition, in at least sonic embodiments, a frictional force F130′ acts atpoint 130 to resist slipping ofthreads section 110A indirection 127. As a result, torque T130 and friction force F130′ drive the rotation ofsection 110A aboutaxis 125A in adirection 129. Rotation ofsection 110A aboutaxis 125A can be further supplemented by an external device such as a spinner assembly or tongs. The orbiting and rotation can be accomplished by any device known in the art, such as by modified tongs with eccentrics, gears, hydraulic cylinders, radial impacts and resonance machines. - In at least some embodiments, once
section 110A begins rotating aboutaxis 125A (whether by torque T130 and/or force F130′ alone or in combination with an external device), a second frictional force F130″ also acts onsections threads section 110A relative tosection 110B. Force F130″ is analogous to the friction force that must be overcome during conventional makeup operations. However, as is shown inFIGS. 4 and 5 , force F130′ and torque T130 are each operate in the opposite direction as force F130″, and thus, at least partially counteract force F130″. Consequently, the overall or net frictional force directly resisting rotation ofsection 110A relative tosection 110B is reduced. Thus, by inducingsection 110A to orbit aboutaxis 125B ofsection 110B during makeup operations, at least a portion of the friction betweenthreads - During makeup of joint 120 according to the method illustrated in
FIG. 3 ,axis 125A is initially radially offset fromaxis 125B by a radial distance R129, and there is clearance gap X110A-110B radially positioned betweensections opposite contact point 130. However, since mating threadedconnectors sections axis 125A moves or translates towardaxis 125B, radial distance R129 decreases, and clearance gap X110A-110B decreases. In other words, as joint 120 is made-upaxis 125A spirals inward towardaxis 125B. As radial distance R129 and clearance gap X110A-110B decrease and axes 125A, 125B come into coaxial alignment, the orbital and rotational motions ofsection 110A relative tosection 110B transition to pure rotation ofsection 110A relative tosection 110B about alignedaxes - Referring now to
FIG. 6 , another embodiment of a method for making up threaded joint 120 betweenconnectors sections upper section 110A is canted or angled relative to lower section such thataxis 125A is disposed at an acute angle θ relative to axis 1252 of lower section 1102 during makeup ofjoint 120. At least initially the beginning of the makeup), angle θ is preferably greater than 0.1°. In some embodiments, the angle θ is chosen such that the moment that generate angle θ has a magnitude which is approximately 10% of the connector capacity (In some embodiments, connector capacity refers to the force that generates a bending moment which results in plastic deformation and/or failure ofsection 110A). Thereafter, end 112 a ofsection 110A is driven to orbit aboutaxis 125B indirection 127 to produce the same or a similar whirl or orbit oflower end 112 b ofsection 110A relative tosection 110B as previously described and shown inFIGS. 4 and 5 . In some embodiments, asend 112 a ofsection 110A is rotated about theaxis 125B in thedirection 127 as described above, the rotational path ofsection 110A defines a conical shape. - The method for making up threaded joint 120 shown in
FIG. 6 offers the potential to reduce the torque required to fully make up joint 120. In particular, without being limited to this or any other theory, as previously described and shown inFIGS. 4 and 5 , assection 110A is orbited aboutaxis 125B indirection 127, torque T130 and frictional force F130′ drive the rotation ofsection 110A aboutaxis 125A indirection 129. Rotation ofsection 110A aboutaxis 125A can be supplemented by an external device such as a spinner assembly or tongs. In addition, second frictional force F130″ acts onsections threads section 110A relative tosection 110B. Torque T130 and Force F130″, each operate in the opposite direction as force F130″, and thus, at least partially counteracts force F130″, thereby reducing the total amount of input torque required to fully make upsections - Since mating threaded
connectors sections FIG. 6 , angle θ steadily decreases,axis 125A pivots toward axis 125, radial distance R129 decreases, and clearance gap X110A-110B decreases. As the connection is made up the radial force required to keep R129 positive and rotating increases as the radial friction between the threads and between the shoulders increases. - Referring now to
FIGS. 7-9 , an embodiment of a method for breaking threaded joint 120 betweenconnectors sections lower end 112 b ofupper section 110. A is whirled or orbited aboutaxis 125B oflower section 110B. - The method for breakup of threaded joint 120 shown in
FIG. 7 offers the potential to reduce the torque required to fully break up joint. In particular, as best shown inFIGS. 8 and 9 , without being limited to this or any other theory assection 110A orbits aboutaxis 125B ofsection 110B in adirection 131, a torque T131 is generated that is applied tosection 110A (i.e., a torsional force results from the induced orbital motion) and a force F131′ act onsections contact point 130 to resist slipping ofthreads section 110A about itsown axis 125A indirection 133. Rotation ofsection 110A aboutaxis 125A can he supplemented by an external device such as a spinner assembly or tongs. - Further, as
section 110A rotates about itsaxis 125B, a second frictional force F131″ resists slipping betweenthreads section 110A aboutaxis 125A relative tosection 110B. Force F131″ is analogous to the friction that resists relative rotation ofsections FIGS. 8 and 9 , torque T130 and force F131′ operate in the opposite direction as force F130″, and thus, at least partially counteract force F130″. Consequently, the overall or net frictional force directly resisting rotation ofsection 110A relative tosection 110B is reduced. Thus, by inducingsection 110A to orbit aboutaxis 125B ofsection 110B during breakup operations, at least a portion of the friction betweenthreads - Referring now to
FIG. 10 , another embodiment of a method for breaking up threaded joint 120 betweenconnectors sections upper section 110A is canted or angled relative to lower section such thataxis 125A is disposed at an acute angle φ relative toaxis 125B oflower section 110B during breakup of joint 120. In some embodiments, towards the end of breakup, angle φ is preferably greater than 0.1°. Thereafter, end 112 a ofsection 110A is driven to rotate aboutaxis 125B in adirection 133 to produce the same or a similar whirl or orbit oflower end 112 b ofsection 110A relative tosection 110B indirection 131 as previously described and shown inFIGS. 8 and 9 . - The method for breaking up threaded joint 120 shown in
FIG. 10 offers the potential to reduce the torque required to fully brake up joint 120. In particular, as previously described and shown inFIGS. 8 and 9 , assection 110A is orbited aboutaxis 125B indirection 131, torque T131 and frictional force F131, drive the rotation ofsection 110A aboutaxis 125A in direction 139. Rotation ofsection 110A aboutaxis 125A can be supplemented by an external device such as a spinner assembly or tongs. In addition, second frictional force F131″ acts onsections threads section 110A relative tosection 110B. Torque T131 and force F131′ are in the opposite direction as force F131″, and thus, at least partially counteract force F131″. - Referring now to
FIG. 11 , an embodiment of adevice 200 in accordance with the principals described herein for inducing the orbital motion ofupper section 110A relative to lowersection 110B as described above and shown inFIGS. 3 , 6, 7 and 10 to makeup and breakup joint 120 is shown. During makeup and breakup operations,lower section 110B is held/maintained in position, whiledevice 200 graspsupper section 110A and inducessection 110A to orbit aboutaxis 125B ofsection 110B. In this embodiment,device 200 can also induce rotation ofsection 110A about itsown axis 125A (in addition to inducing the orbital motion aboutaxis 125B). In general,device 200 can be any suitable device known in the art. For example,device 200 can comprise a power tong that induces rotation ofsection 110A aboutaxis 125B ofsection 110B and/or angularly deflectssection 110A relative tosection 110B such that theaxis 125A is canted or angled relative to theaxis 125B, while also rotatingupper end 112 a relative tolower end 112 b ofsection 110A. As another example,device 200 can comprise a motor with an eccentric mass, such that actuation of motor causes a radial rotating shear force and/or being moment at the connection betweensections axis 125A ofsection 110A aboutaxis 125B ofsection 110B. As still another example, in other embodiments,device 200 is an impact wrench or other similarly powered tool that engages withsection 110A and imparts a force thereto which induces orbital motion ofaxis 125A ofsection 110A aboutaxis 125B ofsection 110B. - In this embodiment,
device 200orients section 110A parallel tosection 110B to produce the relative motions of thesections FIGS. 3 and 7 . It is to be understood that for tapered threads, as for drill pipe connections, that during makeup of joint 120, radial distance R129, and clearance gap X110A-110B steadily decrease from a maximum to zero or a small value, and during breakup of joint 120, radial distance R129, and clearance gap X110A-110B steadily increase from zero or a small value to a maximum. In other embodiments, the device (e.g., device 200) can orientsection 110A (or at least the upper portion thereof) at an acute angle θ or φ as described above and shown inFIGS. 6 and 10 to makeup and breakup joint 120, respectively. It is to be understood that in some embodiments, during makeup of joint 120, angle θ, radial distance R129, and clearance gap X110A-110B steadily decrease from a maximum to zero or a small value, and during breakup of joint 120, angle φ, radial distance R129, and clearance gap X110A-110B steadily increase from zero or a small value to a maximum. However, due to the threads being typically triangular and at least in part to the flexibility of the material making upsections - In the manner described,
upper section 110A is manipulated and moved relative to a stationarylower section 110B to makeup and breakup threaded joint 120. However, it should be appreciated that such relative motion ofsections lower section 110B or manipulating bothsections lower section 110B can be manipulated and moved relative to a stationaryupper section 110A (lower section 110B orbited aboutaxis 125A ofupper section 110A withsection 110B parallel tosection 110A or withsections FIG. 12 ,device 200 is shown grasping and movinglower section 110B such that it orbits aboutaxis 125A of stationaryupper section 110A in adirection 227 to makeup threaded joint 120. Aslower section 110B orbits aboutaxis 125A indirection 227,upper section 110A rotates about itsaxis 125A in direction 129 (e.g., by torque T130 and/or force F130′ alone or in combination with some other input force, each as previously described). In the same manner as previously described, this method offers the potential to reduce the total input torque necessary tomakeup joint 120. As yet another example, bothsections axis lower section 110B orbited aboutaxis 125A ofupper section 110A andupper section 110A orbited aboutaxis 125B withsections sections - Referring now to
FIG. 13 , an embodiment of amethod 300 for making up a tubular string (e.g., drillstring 50) is shown,.Method 300 begins atblock 305 by inserting (i.e., lowering) the tubular string at least partially into a bore hole with the upper end of the tubular string extending upward therefrom. In general, the tubular string can be formed from one or more tubular section(s) (e.g.,tubular section block 310, a new tubular section is lowered until the lower end of the new tubular section axially abuts and engages the upper end of the tubular string. Once the new tubular section has engaged the tubular string, the new tubular section is orbited about the central axis of the tubular string atblock 315 in the manner previously described above forsections block 320, the new tubular section is rotated about its central axis while orbiting about the central axis of the tubular string. As a result of the orbiting and rotating inblocks block 325, thereby lengthening the tubular string. Next, the tubular string with the newly incorporated tubular section is lowered further into the borehole inblock 330. Thereafter, thesteps method 300 can be performed in reverse to unthread and remove tubular sections from the tubular string. While making up the orbit drive can be started just when the connection make up torque start to rise rapidly to assist in the torqueing up of the connection. While breaking the orbit motion can be done just at the beginning to assist in the break up. - In the manner described, systems and methods described herein offer the potential to reduce the total torque necessary to makeup and breakup threaded joints between tubular sections by inducing orbital motion(s) in one or both tubular sections (e.g.,
sections threads 117, 119) and outer surfaces (e.g.,surface 112 c) of tubular sections. In addition, the reduced torque loads also results in a reduced value of the resulting residual stresses which occur within such threaded connections, which thereby guards against subsequent loosening of the joint after makeup. - While embodiments disclosed herein have included methods of makeup and breakup of
tubular sections FIG. 14 , anut 402 is shown threadably engaged with a threadedrod 410. In this embodiment,nut 402 is a standard, conventional hexagonal nut but may be any suitable type of bolt known in the art. In addition, in thisembodiment nut 402 has acentral axis 405 and includes a first orupper side 402 a, a second orlower side 402 b opposite theupper side 402 a, and athroughbore 404 extending axially between thesides Rod 410 has acentral axis 415, afirst end 410 a, asecond end 410 b opposite thefirst end 410 a, and a radiallyouter surface 410 c extending between theends surface 410 c and are configured to engage with the internal threads (not shown) disposed withinthroughbore 404 ofnut 402. During operation,nut 402 is disposed onrod 410 such that theaxis 405 is parallel to theaxis 410. Thereafter,axis 405 ofnut 402 is orbited about theaxis 415 ofrod 410 along anorbital path 418 which further results in the rotation ofnut 402 aboutaxis 405 along thedirection 420, For the same reasons previously described above forsections nut 402 alongpath 418 operates to rotate thenut 402 around therod 410 as it rolls without slipping around therod 410, and thus reduces the effective amount of friction opposing the engagement between the corresponding threads ofnut 402 androd 410 which therefor reduces the required amount of input torque necessary to threadably engagenut 402 androd 410 during operations. - While embodiments disclosed herein have been described as being used in an offshore drilling and/or production system system 10) in other embodiments, the principles disclosed herein may be applied to any drilling and/or production system (e.g., a land-based drilling and/or production system) while still complying with the principles disclosed herein. Thus, any reference in the above disclosure to offshore drilling and/or production systems is merely included to provide context to the description above and is in no way meant to limit the scope thereof. Additionally, while embodiments disclosed herein have described the methods and/or devices as being carried out on sections of drill pipe, it should be appreciated that in other embodiments, the methods and/or device disclosed herein may be used to perform makeup/breakup operations for any type of elongate threaded tubular member, such as, for example, tubing, casing pipes, risers, etc. Thus, any mention of drill pipes is not meant to limit the application of the principles disclosed herein in any way, and is only included to provide context to the description above.
- Further, while embodiments disclosed herein have included threaded
connections connections FIG. 15 , for threaded connections that are not tapered,outer surface 112 c of eachbody 112 is disposed at an outer diameter D110o, andinner surface 112 d of eachbody 112 is disposed at an inner diameter D110i. Outer surface 112 c is cylindrical betweenupper end 112 a and pin-end connector 118 a, and is cylindrical alongconnector 118 a. Thus, outer diameter D110o is uniform betweenend 112 a andlower end 112 b.Inner surface 112 d is cylindrical betweenlower end 112 b and box-end connector 116 a, and is cylindrical alongconnector 116 a. Thus, inner diameter D110i is uniform betweenend 112 b andlower end 112 a. - During makeup of joint 120 with cylindrical threaded connections according to the method illustrated in
FIG. 3 ,axis 125A is radially offset fromaxis 125B by a radial distance R129, and there is clearance gap X110A-110B radially positioned betweensections opposite contact point 130. As joint 120 is made-up,axis 125A remains a constant distance fromaxis 125B, radial distance R129 stays constant, and clearance gap X110A-110B stays constant until the shoulders make contact. The orbit radius is reduced as the triangular thread contact surfaces force the pin and box axis together. Rotation stops when the friction between the threads and the shoulder exceed the combine twisting torque and the orbital radial force. - The embodiments described in reference to
FIGS. 6 and 9 apply in the same fashion for threaded connections that are not tapered. The orbit radius is reduced as the triangular thread contact surfaces force the pin and box axis together. Rotation stops when the friction between the threads and the shoulder exceed the combine twisting torque and the orbital radial force. - The embodiments described in reference to
FIGS. 7 and 10 apply in the same fashion to break up a joint 120 with threaded connections that are not tapered. - While preferred embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simplify subsequent reference to such steps.
Claims (24)
1. A method for making a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end, the method comprising:
(a) moving the first tubular axially relative to the second tubular to position the pin-end connector of the first tubular at least partially within the box-end connector of the second tubular;
(b) orbiting the pin-end connector of the first tubular about the central axis of the second tubular;
(c) rotating the first tubular about the central axis of the first tubular during (b); and
(d) threading the pin-end connector of the first tubular into the box-end connector of the second tubular during (b) and (c).
2. The method of claim 1 , further comprising maintaining the central axis of the first tubular parallel to the central axis of the second tubular during (b) and (c).
3. The method of claim 2 , further comprising:
radially offsetting the central axis of the first tubular from the central axis of the second tubular by a radial offset distance;
decreasing the radial offset distance during (d).
4. The method of claim 1 , further comprising orienting the first tubular at an acute angle θ relative to the second tubular during (b) and (c).
5. The method of claim 4 , further comprising decreasing angle θ during (d).
6. The method of claim 1 , further comprising spiraling the central axis of the second tubular inward relative to the central axis of the first tubular during (b) and (c).
7. The method of claim 1 , wherein (c) occurs in response to (b).
8. The method of claim 1 , further comprising driving the rotation of the first tubular about the central axis of the first tubular during (c) with a device removably coupled to the first tubular.
9. A method for breaking a threaded joint between a first elongate tubular and a second elongate tubular, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector at the first end, and an externally threaded pin-end connector at the second end, the method comprising:
(a) orbiting the pin-end connector of the first tubular about the central axis of the second tubular;
(b) rotating the first tubular about the central axis of the first tubular during (a); and
(c) unthreading the pin-end connector of the first tubular from the box-end connector of the second tubular during (a) and (b); and
(d) moving the first tubular axially relative to the second tubular to remove the pin-end connector of the first tubular from the box-end connector of the second tubular.
10. The method of claim 9 , further comprising maintaining the central axis of the first tubular parallel to the central axis of the second tubular during (a) and (b).
11. The method of claim 10 , further comprising increasing a radial offset distance between the central axis of the first tubular and the central axis of the second tubular during (d).
12. The method of claim 9 , further comprising increasing an acute angle θ between the central axis of the first tubular and the central axis of the second tubular during (a) and (b).
13. The method of claim 9 , further comprising spiraling the central axis of the second tubular outward relative to the central axis of the first tubular during (a) and (b).
14. The method of claim 9 , wherein (b) occurs in response to (a).
15. A method for assembling a tubular string for an oil and gas operation, wherein the tubular string comprises a plurality of elongate threaded tubulars, each tubular including a central axis, a first end, a second end opposite the first end, a throughbore extending between the first end and the second end, an internally threaded box-end connector disposed at the first end, and an externally threaded pin-end connector disposed at the second end, the method comprising:
(a) lowering the tubular string into a borehole;
(b) lowering a first tubular axially toward the tubular string to position the pin-end connector of the first tubular into a box-end connector disposed at an upper end of the tubular string;
(c) orbiting the pin-end connector of the first tubular about the central axis of the tubular string;
(d) rotating the first tubular about the central axis of the tubular string during (c); and
(e) threading the pin-end connector of the first tubular into the box end connector of the tubular string during (c) and (d) to lengthen the tubular string.
16. The method of claim 15 , further comprising maintaining the central axis of the first tubular parallel to the central axis of the tubular string during (c) and (d).
17. The method of claim 16 , further comprising decreasing a radial offset distance between the central axis of the first tubular and the central axis of the tubular string during (e).
18. The method of claim 15 , further comprising decreasing an acute angle θ between the central axis of the first tubular and the central axis of the tubular string during (e).
19. The method of claim 15 , wherein (d) occurs in response to (c).
20. The method of claim 15 , further comprising:
(f) lowering the tubular string further into the borehole after (e);
(g) lowering a second tubular axially toward the tubular string to position the pin-end connector of the second tubular into a box-end connector disposed at an upper end of the first tubular;
(h) orbiting the pin-end connector of the second tubular about the central axis of the first tubular;
(i) rotating the second tubular about the central axis of the first tubular during (h); and
(j) threading the pin-end connector of the second tubular into the box end connector of the first tubular during (h) and (i) to lengthen the tubular string.
21. A method for making a threaded connection between a threaded rod and a bolt, where the threaded rod includes a central axis, a first end, a second end opposite the first end, a radially outer surface extending between the first end and second end, and where the radially outer surface includes a set of external threads, and where the bolt includes a central axis, a first end, a second end opposite the first end, and has a throughbore extending axially between the first end and second end, and where the bolt has a set of internal threads, the method comprising:
(a) disposing the bolt onto the threaded rod such that the axis of the bolt is parallel to the axis of the threaded rod;
(b) orbiting the bolt about the central axis of the threaded rod;
(c) rotating the bolt about the central axis of the bolt during (b); and
(d) threadably engaging the internal threads of the bolt with the external threads of the threaded rod during (b) and (c).
22. The method of claim 21 , further comprising maintaining the central axis of the bolt parallel to the central axis of the threaded rod during (b) and (c).
23. The method of claim 21 , further comprising decreasing a radial offset distance between the central axis of the bolt and the central axis of the threaded rod during (d).
24. The method of claim 21 , further comprising decreasing an acute angle θ between the central axis of the first tubular and the central axis of the tubular string during (d).
Priority Applications (1)
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US14/548,412 US20150135501A1 (en) | 2013-11-20 | 2014-11-20 | Systems and methods for making and breaking threaded joints using orbital motions |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US201361906696P | 2013-11-20 | 2013-11-20 | |
US14/548,412 US20150135501A1 (en) | 2013-11-20 | 2014-11-20 | Systems and methods for making and breaking threaded joints using orbital motions |
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US20150135501A1 true US20150135501A1 (en) | 2015-05-21 |
Family
ID=52014408
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US14/548,412 Abandoned US20150135501A1 (en) | 2013-11-20 | 2014-11-20 | Systems and methods for making and breaking threaded joints using orbital motions |
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US (1) | US20150135501A1 (en) |
WO (1) | WO2015077408A2 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
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US20190218908A1 (en) * | 2013-03-07 | 2019-07-18 | Evolution Engineering Inc. | Detection of downhole data telemetry signals |
Citations (3)
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US2354460A (en) * | 1940-12-16 | 1944-07-25 | Logansport Machine Inc | Hydraulic tube coupling |
US20090214317A1 (en) * | 2008-02-22 | 2009-08-27 | Newfrey Llc | Weld stud |
US20150034388A1 (en) * | 2013-07-31 | 2015-02-05 | National Oilwell Varco, L.P. | Downhole motor coupling systems and methods |
Family Cites Families (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JPS60123234A (en) * | 1983-12-08 | 1985-07-01 | Kawasaki Steel Corp | Screwing method of tapered screw |
JPS618239A (en) * | 1984-06-25 | 1986-01-14 | Kawasaki Steel Corp | Automatic mounting apparatus for pipe end protector |
JPH0643016B2 (en) * | 1984-08-15 | 1994-06-08 | 日本鋼管株式会社 | How to fit screws |
JPS6374532A (en) * | 1986-09-13 | 1988-04-05 | Nippon Steel Corp | Adaption kit fitting method to steel pipe end and its device |
-
2014
- 2014-11-20 WO PCT/US2014/066537 patent/WO2015077408A2/en active Application Filing
- 2014-11-20 US US14/548,412 patent/US20150135501A1/en not_active Abandoned
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
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US2354460A (en) * | 1940-12-16 | 1944-07-25 | Logansport Machine Inc | Hydraulic tube coupling |
US20090214317A1 (en) * | 2008-02-22 | 2009-08-27 | Newfrey Llc | Weld stud |
US20130259597A1 (en) * | 2008-02-22 | 2013-10-03 | Newfrey Llc | Weld stud |
US8998549B2 (en) * | 2008-02-22 | 2015-04-07 | Newfrey Llc | Weld stud |
US20150034388A1 (en) * | 2013-07-31 | 2015-02-05 | National Oilwell Varco, L.P. | Downhole motor coupling systems and methods |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
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US20190218908A1 (en) * | 2013-03-07 | 2019-07-18 | Evolution Engineering Inc. | Detection of downhole data telemetry signals |
US10570726B2 (en) * | 2013-03-07 | 2020-02-25 | Evolution Engineering Inc. | Detection of downhole data telemetry signals |
Also Published As
Publication number | Publication date |
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WO2015077408A3 (en) | 2015-10-22 |
WO2015077408A2 (en) | 2015-05-28 |
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