WO2016163986A1 - Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production - Google Patents

Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production Download PDF

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Publication number
WO2016163986A1
WO2016163986A1 PCT/US2015/024579 US2015024579W WO2016163986A1 WO 2016163986 A1 WO2016163986 A1 WO 2016163986A1 US 2015024579 W US2015024579 W US 2015024579W WO 2016163986 A1 WO2016163986 A1 WO 2016163986A1
Authority
WO
WIPO (PCT)
Prior art keywords
body portion
compliant
tubing string
expandable segments
slip device
Prior art date
Application number
PCT/US2015/024579
Other languages
English (en)
Inventor
Matthew B. ROSEMAN
Original Assignee
Halliburton Energy Services, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to US15/028,319 priority Critical patent/US20170260823A1/en
Priority to PCT/US2015/024579 priority patent/WO2016163986A1/fr
Publication of WO2016163986A1 publication Critical patent/WO2016163986A1/fr

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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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/01—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/128—Packers; Plugs with a member expanded radially by axial pressure
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/134—Bridging plugs

Definitions

  • the compliant slip assembly can include a
  • compliant slip device with a body that can have a rigid first portion, a compliant second portion, and an expandable third portion, where expanding the third portion secures the well tool in the tubing string.
  • the compliant slip assembly is used in an oil or gas well operation.
  • FIG. 1 depicts a cross-sectional view of a wellbore containing a frac plug that includes multiple compliant slip assemblies for securing the frac plug in the wellbore.
  • Fig. 2 depicts a cross-sectional view of the frac plug of Fig. 1 without the wellbore and surrounding earth formation being shown.
  • FIGs. 3A - C depict multiple views of a compliant slip device according to certain embodiments that can be
  • Figs. 4A - C depict multiple views of a compliant slip assembly according to certain embodiments in an unexpanded configuration .
  • Figs. 5A - C depict multiple views of a compliant slip assembly according to certain embodiments in an expanded configuration .
  • Figs. 6A - B depict multiple views of a compliant slip assembly according to certain other embodiments in an unexpanded configuration.
  • Figs. 7A - B depict multiple views of a compliant slip assembly according to certain other embodiments in an unexpanded configuration.
  • Oil and gas hydrocarbons are naturally occurring in some subterranean formations.
  • a subterranean formation containing oil or gas is referred to as a reservoir.
  • a reservoir may be located under land or off shore.
  • Reservoirs are typically located in the range of a few hundred feet (shallow reservoirs) to tens of thousands of feet (ultra- deep reservoirs) .
  • a wellbore is drilled into a reservoir or adjacent to a reservoir.
  • the oil, gas, or water produced from a reservoir is called a reservoir fluid.
  • a "fluid” is a substance having a continuous phase that tends to flow and to conform to the outline of its container when the substance is tested at a temperature of 71 °F (22 °C) and a pressure of one atmosphere (atm) (0.1 megapascals (MPa) ) .
  • a fluid can be a liquid or gas.
  • a well can include, without limitation, an injection well, or an oil, gas, or water production well.
  • a well includes at least one wellbore.
  • wellbore can include vertical, inclined, and horizontal
  • the term “wellbore” includes any cased, and any uncased, open-hole portion of the wellbore.
  • the well can also include multiple wellbores, such as a main wellbore and lateral wellbores.
  • the term “wellbore” also includes a main wellbore as well as lateral wellbores that branch off from the main wellbore or from other lateral wellbores.
  • a near- wellbore region is the subterranean material and rock of the subterranean formation surrounding the wellbore.
  • a "well” also includes the near-wellbore region.
  • the near-wellbore region is generally considered to be the region within approximately 100 feet radially of the wellbore.
  • into a well means and includes into any portion of the well, including into the wellbore or into the near-wellbore region via the wellbore.
  • a tubing string may be placed into the wellbore.
  • the tubing string allows fluids to be introduced into or flowed from a remote portion of the wellbore.
  • a casing is placed into the wellbore that can also contain a tubing string.
  • a wellbore can contain an annulus .
  • annulus examples include, but are not limited to, the space between the wellbore and the outside of a tubing string in an open-hole wellbore; the space between the wellbore and the outside of a casing in a cased-hole wellbore; and the space between the inside of a casing and the outside of a tubing string in a cased-hole wellbore .
  • the subterranean formation can have different zones.
  • a zone is an interval of rock differentiated from surrounding rocks on the basis of its fossil content or other features, such as faults or fractures. For example, one zone can have a higher permeability compared to another zone.
  • Each zone of the formation can be isolated within the wellbore via the use of packers, frac plugs, or other similar devices. At least one wellbore interval corresponds to each zone.
  • first,” “second,” “third,” etc. are arbitrarily assigned and are merely intended to differentiate between two or more materials, isolation devices, wellbore intervals, etc., as the case may be, and does not indicate any particular orientation or sequence. Furthermore, it is to be understood that the use of the term “first” does not require that there be any "second, " and the use of the term “second” does not require that there be any "third, " etc.
  • a bridge plug is composed primarily of slips, a plug mandrel, and a rubber sealing element.
  • a bridge plug can be introduced into a wellbore and the sealing element can be caused to block fluid flow into downstream intervals.
  • a packer generally consists of a sealing device, a holding or setting device, and an internal flow passage for fluids.
  • a packer can be used to block fluid flow through the annulus located between the outside of a tubular and the wall of the wellbore or inside of a casing.
  • a frac plug generally consists of slips, a plug mandrel, a rubber seal element, and an internal flow passage for fluids.
  • the frac plug can be introduced into a wellbore to block fluid flow into downstream elements, similar to a bridge plug.
  • the frac plug in addition to the rubber seal element that seals an annulus between the plug mandrel and the tubing string, the frac plug has an internal flow passage that must be blocked to prevent fluid flow to downstream intervals.
  • An object can be dropped or circulated to a seal seat, thereby blocking fluid flow through the internal flow passage.
  • Isolation devices can be classified as permanent or retrievable. While permanent isolation devices are generally designed to remain in the wellbore after use, retrievable devices are capable of being removed after use. It is often desirable to use a retrievable isolation device in order to restore fluid communication between one or more wellbore intervals.
  • isolation devices are retrieved by inserting a retrieval tool into the wellbore, wherein the retrieval tool engages with the isolation device, attaches to the isolation device, and the isolation device is then removed from the wellbore.
  • Another way to remove an isolation device from the wellbore is to mill at least a portion of the device or the entire device.
  • another way to remove an isolation device is to contact the device with a solvent, such as an acid, thus dissolving all or a portion of the device.
  • the slips in these isolation devices can be a slip ring assembly with multiple slip segments for securing an isolation device in a tubing string.
  • a slip ring assembly that can include individual slip segments assembled in a ring around a mandrel and held in place by one or more bands. The inclusion of the bands requires additional manufacturing steps, thereby increasing the cost of the slip assembly.
  • a wedge ring can be used to expand the slip segments into gripping engagement with an inside wall of the tubing string.
  • the wedge ring can be forced underneath the ring of segments, thereby producing sufficient radial force to fracture the bands.
  • the fractured bands release the slip segments and allow radial expansion of the slip segments into contact with the tubing string.
  • the fractured bands can become trapped between the segments and tubing string, thereby undermining their gripping engagement with the tubing string and reducing a gripping force of the slip assembly.
  • the fractured bands can also become trapped between an expandable seal element and the tubing string, thereby possibly causing leakage around the device.
  • Another example for retaining slip segments on a mandrel is to make the slip segments as a single piece ring with longitudinal fracture sites between each potential slip segment.
  • Each fracture site can be a longitudinal recess cut into an outer and/or inner surface of the slip device assembly or the fracture site can be a thin interface between the slip segments.
  • the fracture sites can fracture, resulting in multiple individual slip segments that can then be expanded into gripping engagement with the tubing string.
  • this example can also cause problems. When one or more of the fracture sites are fractured, less force can be applied to the remaining fracture sites due to the separation of some slip segments from the single piece ring.
  • compliant slip device can reduce or eliminate the problems of the slip device assembly examples given above.
  • "compliant” refers to a material that can undergo deformation (e.g., elastic, plastic, etc.) when subjected to an applied force, and the deformation is performed without fracturing.
  • a thin piece of metal (or any other suitable material) connected between two rigid objects may bend or fold when one of the objects moves relative to the other object, but the thin metal does not lose connection between the objects during the deformation.
  • the thin metal can also be designed to fracture after it undergoes a predetermined amount of
  • a compliant slip assembly for securing tools in a tubing string, where the compliant slip assembly can include a wedge ring and a compliant slip device.
  • the compliant slip device can include a body with a substantially constant outer diameter from a first end to a second end when the slip device is unexpanded, and the body can include first, second, and third portions, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are circumferentially spaced apart with a slit between adjacent expandable segments .
  • a method of securing a well tool in a tubing string can include conveying the well tool with a compliant slip assembly to a predetermined location in the tubing string, where the compliant slip assembly can include a wedge ring and a compliant slip device.
  • the compliant slip device can include a body with a substantially constant outer diameter from a first end to a second end when the slip device is unexpanded, and the body can include first, second, and third portions, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are circumferentially spaced apart with a slit between adjacent expandable segments .
  • the method can also include expanding the compliant slip assembly into engagement with the tubing string, thereby securing the well tool in the tubing string.
  • a compliant slip device can include a body with a substantially constant outer diameter from a first end to a second end when the
  • compliant slip device is in an unexpanded configuration, and first, second, and third portions of the body, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are
  • the body can be a single piece with the first, second, and third body portions integral to the body, with the second body portion formed between the first and third body portions, and the second body portion being deformed to allow the third body portion to radially expand while the first body portion is prevented from expanding.
  • a "single-piece" body can include 1) a body that is made from a single block of material, 2) a body that is made from a mold that forms a single body, 3) a body that is formed from bonding multiple pieces together to form the body, where each piece can include one or more expandable segments, and 4) a body that is made by fastening individual pieces together to form the body, where each piece can include one or more expandable segments, etc. - so long as the final product yields a single body that can be installed in an assembly as one piece.
  • the single body can be slipped onto a mandrel as a single piece when assembling a compliant slip assembly 32, 36 ⁇ see Figs. 1, 2) .
  • Gripping devices, such as buttons, wickers, etc. can be fixed to the body, however the body is still considered to be a single- piece body.
  • a compliant slip device can include a body with a substantially constant outer diameter from a first end to a second end when the
  • compliant slip device is in an unexpanded configuration, and first, second, and third portions of the body, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are
  • the compliant slip device can be introduced into the wellbore without a retainer ⁇ e.g., one or more bands, molded ring, etc.) being positioned external to the compliant slip device, where the "retainer" is used herein to mean a device or structure that is used to prevent radial expansion of the expandable segments during the introduction and/or positioning of the compliant slip device at a
  • the expandable segments can be expanded downhole without fracturing and/or breaking a material or structure that would prevent expansion of the segments prior to the fracturing or breaking of the material or structure.
  • a compliant slip assembly for securing tools within a tubing string, where the compliant slip assembly can include a wedge ring and a compliant slip device.
  • the compliant slip device can include a body with a substantially constant outer diameter from a first end to a second end when the slip device is unexpanded, and the body can include first, second, and third portions, where the first portion is rigid, the second portion is
  • the third portion includes multiple expandable segments that are circumferentially spaced apart with a slit between adjacent expandable segments. Engagement of the
  • expandable segments with a tubing string causes the second portion to fracture, which disconnects the expandable third body portion from the rigid first body portion after the second body portion undergoes a predetermined deformation.
  • a compliant slip assembly for securing tools within a tubing string, where the compliant slip assembly can include a retainer sleeve, a wedge ring, and a compliant slip device.
  • compliant slip device can include a body with first, second, and third portions, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are circumferentially spaced apart with a slit between adjacent expandable segments.
  • the retainer sleeve encircles the expandable segments and prevents radial expansion of the segments during introduction into the tubing string.
  • a compliant slip assembly for securing tools within a tubing string, where the compliant slip assembly can include a wedge ring and a compliant slip device.
  • the compliant slip device can include a body with first, second, and third portions, where the first portion is rigid, the second portion is compliant, and the third portion includes multiple expandable segments that are circumferentially spaced apart with a slit between adjacent expandable segments.
  • the compliant slip device can include multiple individual expandable segments that can be assembled to a spacer ring by an attachment means to form the body.
  • attachment means refers to items that are attached by bonding ⁇ such as welding, gluing, heat forming, fusion, etc.) and/or fastening (such as with screws, bolts, rivets, etc.).
  • the “attachment means” can also refer to retaining the
  • Fig. 1 depicts a wellbore 10 that has been drilled through an earth formation 20.
  • a tubing string 14 e.g., a casing string
  • cement 12 has filled an annulus between the wellbore and the tubing string 14, and this wellbore
  • the tubing string can be installed in an uncased well without the annulus being filled with cement.
  • the tubing string can also be installed in another tubing string in the wellbore.
  • compliant slip assembly can be used in many wellbore configurations.
  • the first wellbore interval 16 can be associated with a lower formation zone
  • the second wellbore interval 18 can be associated with an upper formation zone. It can be desirable to perform separate
  • the casing of the first wellbore interval 16 is perforated first, and then these perforations are fractured by pumping fracturing fluid into the perforations at a pressure higher than a fracture pressure of the lower zone.
  • perforations are made in the casing of the second wellbore interval 18. It may be desirable to isolate different
  • subterranean formation zones by isolating the first wellbore interval 16 from the second wellbore interval 18 by setting an isolation device (such as a frac plug 30, bridge plug, packer, etc. ) in the tubing string 14 at a location between the first wellbore interval 16 and the second wellbore interval 18.
  • the frac plug 30 (or isolation device) can be run into the tubing string 14 on a conveyance to a desired location in the tubing string 14.
  • “conveyance” refers to a means of transporting the frac plug 30 (or isolation device) through the tubing string 14, such as coiled tubing, a wireline, a tractor system, a segmented tubing string, etc.
  • a setting tool (not shown) connected to the conveyance can be used to set the frac plug 30 at the desired or predetermined location.
  • an object can be dropped to land in a seal seat at an upper end of the frac plug 30, thereby blocking fluid flow through the frac plug 30 and pressure isolating the first wellbore interval 16 from the second wellbore interval 18.
  • the upper zone can then be fractured by pumping the fracturing fluid into the perforations in the second wellbore interval 18 at a pressure higher than a fracture pressure of the upper zone.
  • the frac plug 30 can include an upper compliant slip assembly 32, a seal assembly 34, and a lower compliant slip assembly 36.
  • Fig. 1 depicts the compliant slip assemblies 32, 36 in their initial run-in configuration, where the outer diameter D4 of the compliant slip assemblies is less that the outer diameter D2, which is the maximum outer diameter of the frac plug 30 in the initial ⁇ or unexpanded) configuration.
  • the diameter D2 is less than the inner diameter Dl of the tubing string 14 to facilitate movement of the frac plug 30 through a flow passage 28 of the tubing string 14 to the predetermined location.
  • An upper end 38 of the frac plug 30 can be connected to a setting tool (not shown) and conveyed into the tubing string 14 on the setting tool via a conveyance.
  • the setting tool can be used to set the frac plug 30 by pulling up on the mandrel 26 of the frac plug 30 while forcing the compliant slip assembly 32 down, thereby compressing the slip and seal assemblies 32, 34, 36 and radially expanding these assemblies into engagement with the tubing string 14.
  • the outer diameter D6 of the seal assembly 34 and the outer diameter D4 of the compliant slip assemblies 32, 36 are increased by radial expansion until they are generally equal to the inner diameter Dl of the tubing string 14.
  • the engagement of these assemblies 32, 34, 36 with the tubing string 14 provides a gripping force that prevents further longitudinal movement of the frac plug 30 and seals off an annulus between the frac plug mandrel 26 and the tubing string 14. Therefore, when an object (e.g., ball, dart or other blocking device) is dropped through the tubing string to the frac plug 30 and engages a seal at the end 38, the internal flow passage (with inner diameter D5) is sealed off and wellbore intervals 16, 18 are pressure isolated from each other.
  • an object e.g., ball, dart or other blocking device
  • the frac plug 30 shown in Fig. 1 is only one example of an isolation device that can benefit from the compliant slip assembly of this disclosure.
  • an isolation device such as a bridge plug may not include an internal flow passage. Therefore, dropping balls or darts would not be necessary to pressure isolate the wellbore intervals 16, 18 when the bridge plug is set. Additionally, a packer or other isolation device may benefit from utilizing the compliant slip assemblies 32, 36 of this disclosure.
  • Fig. 2 depicts the frac plug 30 without the surrounding wellbore 10, tubing string 14, or earth formation 20 for clarity.
  • the end 38 of the frac plug can be used to connect to a setting tool (not shown) during run-in.
  • the frac plug 30 can include the compliant slip
  • the upper slip assembly 32 can include a spacer ring 50, a compliant slip device 40 and a wedge ring 60.
  • the spacer ring 50 abuts a shoulder of the mandrel at end 38, which can have a radially enlarged diameter D3.
  • the compliant slip device 40 can be slipped over an end of the spacer ring 50 such that the
  • compliant slip device 40 overlaps a portion of the spacer ring 50.
  • Inclined surfaces 62 on the wedge ring 60 partially engage respective inclined surfaces 44 of the compliant slip device 40.
  • the spacer ring 50 and the wedge ring 60 are depicted as having a shear device 24 that prevents movement of these rings 50, 60 relative to the mandrel 26 during run-in of the frac plug 30.
  • the lower slip assembly 36 is depicted as being very similar to the upper slip assembly 32, except that the spacer ring 50 is shown as a mule shoe 50. However, it should be clearly understood that the spacer ring 50 is not required.
  • the slip device 40 can provide engagement interfaces for an application of a compressive force applied to the slip device 40 and the wedge ring 60 to force the wedge ring 60 underneath the
  • the seal assembly 34 can include an expandable seal element 70 and end rings 72, 74.
  • the wedge ring 60 of the upper slip assembly 32 can abut the end ring 72, and the wedge ring 60 of the lower slip assembly 36 can abut the end ring 74. Moving the upper and lower wedge rings 60 toward each other can result in compressing the seal element 70.
  • the setting tool can apply a tensile force Fl to the mandrel 26 while applying a compressive force F2 to an engagement surface 52 of the spacer ring 50 of the upper slip assembly 32.
  • the tensile force Fl urges the lower slip assembly 36 to move toward the upper slip assembly 32, thereby compressing the components of the
  • various shear devices 24 will shear allowing the components to slide along the mandrel 26.
  • a surface 56 of the spacer ring 50 abuts a surface 42 of the compliant slip device 40, thereby moving the compliant slip device 40 along inclined surfaces 62 of the wedge ring 60 and radially expanding the compliant slip device 40 into
  • the shear device 24 in the upper wedge ring 60 will shear allowing the upper wedge ring 60 to slide on the mandrel 26 toward the lower wedge ring 60, thereby compressing the seal element 70 between the end rings 72, 74 and radially expanding the seal element 70 into engagement with the tubing string 14.
  • compression of the components of the lower slip assembly 36 will shear one or more shear devices 24 and move the compliant slip device 40 along inclined surfaces 62 of the lower wedge ring 60, thereby radially expanding the compliant slip device 40 into gripping engagement with the tubing string 14.
  • the spacer ring (or mule shoe) 50 of the lower slip assembly 36 can be threaded onto the bottom end of the mandrel 26. Therefore, the tensile force Fl applied to the mandrel 26 is transmitted through the threaded connection to the spacer ring 50 of the lower slip assembly 36 and opposes the compressive force F2 applied to the upper spacer ring 50,
  • the shear device 24 in the spacer ring 50 of the lower slip assembly 36 can prevent premature
  • FIG. 3A - C depict various views of the
  • Fig. 3A depicts a perspective view
  • Fig. 3B depicts and end view
  • Fig. 3C depicts a side view of the compliant slip device 40.
  • the compliant slip device 40 can be a single body where all components of the ring 40 are integral to a body 41 ⁇ the
  • gripping devices 22 can be fixedly attached to an outer surface 69 of the body 41 after the body 41 is formed) . Prior to the compliant slip device 40 being expanded, the body 41 is
  • the compliant slip device 40 can include first, second, and third portions 82, 84, 86 of the body 41.
  • the first body portion 82 can be a rigid region of the body of length L2 that does not expand when the compliant slip device 40 is radially expanded into gripping engagement with the tubing string 14.
  • the third body portion 86 can include multiple expandable segments 90 with adjacent ones (or pairs) of the expandable segments 90, each being separated by a longitudinally extending slit 92.
  • the second body portion 84 can be a compliant region 98 disposed between the first body portion 82 and the third body portion 86.
  • the compliant region 98 can allow the third body portion 86 to radially expand while
  • the first body portion 82 includes an inner surface 48 and an outer surface 49.
  • the second body portion 84 includes an inner surface 58 and an outer surface 59.
  • the third body portion 86 includes an inner surface 68 and an outer surface 69.
  • the outer surfaces 49, 59 and 69 can form a
  • the slits 92 can be longitudinally extending regions of the compliant slip device 40 that are void of material.
  • the inner surfaces 48, 58 and 68 can form generally cylindrical surfaces with various inner diameters to facilitate operation with the spacer ring 50 and the wedge ring 60.
  • the inner surfaces 48 and 58 can have generally the same diameter D8 when the compliant slip device 40 is in the unexpanded
  • the diameter D9 of the inner surface 68 can be radially reduced from the inner diameter D8 of the inner surface 58, thereby forming a shoulder 42 on each of the expandable segments 90 at the transition between the inner surfaces 58, 68.
  • the inner surface 68 can form an inclined surface 44 with a diameter that increases from the diameter D9 to a diameter D7 at the end 47 of the body 41 (diameter D7 and inclined surface 44 not shown, refer to Fig. 2) .
  • This inclined surface 44 can be used to radially expand the expandable segments 90 when the wedge ring 60 is forced into the end 47 of the body 41.
  • the inclined surface 44 can also be an annular arrangement of inclined planar surfaces, where a cross-sectional view of the inclined surface 44 can be the shape of a triangle, square, pentagon, hexagon, etc., depending on the number of inclined planar surfaces utilized.
  • Each slit 92 can extend longitudinally through the second body portion 84 and at least partially through the third body portion 86.
  • Each slit 92 can be formed with a constant width Wl when the compliant slip device 40 is in the unexpanded configuration. These slits 92 allow the individual segments 90 to move independently when the compliant slip device 40 is being expanded. The slits 92 may not extend into the first body portion 82 because it is desirable that the first body portion 82 remain rigid and not expand during expansion of the second and third body portions 84, 86. However, these slits can also extend through the first body portion. A portion of each individual expandable segment can be fixedly attached by an attachment means to form a rigid first body portion.
  • Each slit 92 includes an end 94 and an opposite end 96, where the end 96 is near the end 47 of the body 41, and the end 94 can be near a transition between the first and second body portions 82, 84.
  • the length LI is the combination of a length of the compliant region 98 and a length of the third body portion 86.
  • the length L2 of the first body portion is the region that does not expand (i.e., is rigid) .
  • the overall length L3 of the body 41 is the sum of length LI and length L2.
  • These lengths LI, L2 can be adjusted as desired to change various characteristics of the compliant slip device 40, such as: increasing a radial expansion of the third body portion 86 by increasing the compliant region 98; or increasing the rigidity of the first body portion 82 by increasing the length L2, etc.
  • Figs. 3D - F depict detailed views of the end 94 of a slit 92 in Fig. 3C .
  • Figs. 3D — F depict various
  • the slit 92 begins at the end 47 and continues to the end 94 (end 94 shown in Fig. 3C) without any material bridging across the slit 92 for the entire length LI of the slit 92. This allows the expandable segments 90 to move
  • Fig. 3E depicts another configuration of the slit 92, where the slit 92 does not extend to the end 47 of the body 41 due to a tab 88 positioned at the end 47.
  • the tab 88 can be formed by a material of length L4 that bridges between adjacent expandable segments 90. This tab 88 can be used to prevent expansion of the expandable segments 90 until the frac plug 30 is positioned in the tubing string 14 and the setting tool begins to expand the segments via the compression force. When the expandable segments 90 are expanded, the tab 88 is
  • the length of the slit 92 is the length LI minus the length L4 of the tab 88.
  • Fig. 3F depicts yet another configuration of the slit 92, where the tab 88 is positioned at a desired location along the slit 92, thereby dividing the slit 92 into two segments .
  • One segment extends from the end 94 to the tab 88 and the other segment extends from the tab 88 to the end 47 of the body 41.
  • the tab 88 can be formed by a material of length L4 that bridges between adjacent expandable segments 90.
  • the length L4 is preferably less than 20% of the overall length LI that includes the second and third body portions 84, 86. This tab 88 can be used to prevent expansion of the expandable segments 90 until the frac plug 30 is positioned in the tubing string 14 and the setting tool begins to expand the segments via the compression force.
  • each of these tabs 88 may include scores or notches along the inner and/or outer surfaces of the tab 88 to reduce the force needed to fracture these tabs 88 during radial expansion.
  • each slit 92 there may be multiple tabs 88 along each slit 92, thereby dividing each slit 92 into three or more segments.
  • Figs. 4A - C depict the slip assembly 32 in the unexpanded configuration without the other assemblies 34, 36 or the mandrel 26 to more easily show the slip assembly.
  • Figs. 4A - B also depict the slip assembly 32 without the tubing string 14, which is shown in Fig. 4C. Please refer back to Figs. 1 - 2 for the structural relationship between these omitted components and the slip assembly 32.
  • Figs. 4A - B depict the compliant slip device 40 positioned between the spacer ring 50 and the wedge ring 60.
  • Fig. 4A is a perspective view and Fig. 4B is a side view of the slip assembly 32.
  • the wedge ring 60 is depicted as having multiple inclined planar surfaces 62 arranged in an annular ring that is generally shaped as a cone, but a cross-section of the wedge 60 at the inclined surfaces 62 would be octagon shaped, since there are eight planar surfaces on the wedge 60.
  • These inclined surfaces 62 engage with inclined surfaces 44 on the compliant slip device 40 as shown in Fig. 4C.
  • the compliant slip device 40 at least partially overlaps the wedge ring 60 when they are installed on the mandrel 26.
  • the spacer ring 50 is depicted in Fig. 4C as having a generally T-shaped cross section with an internal bore for positioning the ring 50 on the mandrel 26.
  • the spacer ring 50 is inserted into an end 46 of the compliant slip device 40 until the engagement surface 56 of the ring 50 engages each of the shoulders 42 of the expandable segments 90, and the end 46 of the compliant slip device 40 engages (or is at least
  • the compliant slip device 40 can support force engagement and force distribution features of the spacer ring 50 without using a spacer ring 50. In the unexpanded
  • the outer diameter D4 of compliant slip device 40 is substantially constant along the length of the slip device 40.
  • substantially constant, “ substantially equal, “ or “substantially the same” means that the diameter does not vary by more than +/- 10 millimeters when the slip device 40 is in the unexpanded
  • each of the slits 92 is substantially constant along the length of each of the slits 92.
  • width l of each of the slits 92 is substantially constant along the length of each of the slits 92.
  • substantially constant means that the width does not vary by more than +/- 10 millimeters.
  • an outer diameter D4 of the unexpanded compliant slip device 40 is less than the inner diameter Dl of the tubing string 14, thereby allowing unrestricted movement of the slip assembly 32 in the tubing string 14.
  • Figs. 5A - C depict the slip assembly 32 in an expanded configuration without the other assemblies 34, 36 or the mandrel 26.
  • Figs. 5A - B also depict the slip assembly 32 without the tubing string 14, which is shown in Fig. 5C. Please refer back to Figs. 1 - 2 for the structural relationship between these omitted components and the slip assembly 32.
  • Figs. 5A - C depict the slip assembly 32 after the compression force has been applied to the assemblies 32, 34, 36 ⁇ see Fig. 2) via the setting tool.
  • the compression force urges the spacer ring 50 and the wedge ring 60 toward each other and causes movement of the inclined surfaces 44 of the expandable segments 90 along the inclined surfaces 62 on the wedge ring 60.
  • the engagement surface 56 of the spacer ring 50 engages the
  • engagement with the tubing string 14 can cause gripping devices 22 to engage the tubing string 14 by deforming a portion of the tubing string at an engagement site of each gripping device 22.
  • the compliant second body portion 84 can be designed to fracture only after a predetermined deformation of the compliant region 98 has occurred.
  • predetermined deformation means that the second body portion 84 deforms until the expandable third body portion 86 engages the inside of the tubing string 14. When this engagement occurs, the deformation of the second body portion 82 reaches an amount of deformation that causes the engagement segments 90 to fracture at some point along the length of the second body portion 82.
  • the first body portion 82 maintains a diameter D4 (i.e., diameter remains unchanged) , while the third body portion 86 extends to a
  • the first body portion 82 with diameter D4 does not substantially radially expand or contract while the third body portion 86 is being radially expanded.
  • the first body portion 82 is substantially prevented from radially expanding or contracting during expansion of the third body portion 86
  • the terms “remains unchanged, " “does not substantially radially expand or contract, " or “substantially prevented from radially expanding or contracting” means that the diameter of the first body portion is maintained within +/- 10 percent of its initial diameter D4. It can be seen in Figs. 5A - C that the second body portion 84 is deformed to maintain connection between the first and third body portions 82, 86.
  • the second body portion 84 can form a generally frustum-conical shape with diameter Dl at one end and diameter D4 at the other end.
  • the outer surfaces 69 of the third body portion 86 are substantially parallel to the outer surface 49 of the first body portion 82 when the third body portion 86 is in the expanded configuration. In other words, the outer surfaces 69 of the third body portion 86 are coaxially aligned with the outer surface 49 of the first body portion 82.
  • substantially parallel means that the surfaces being compared are within +/- 10 degrees of each other.
  • the portion of the slits 92 in the third body portion 86 have been increased from the width Wl shown in the unexpanded configuration (Figs. 4A — C) to the width W2 shown in the expanded configuration (Figs. 5A - C) .
  • Figs. 6A - B depict a compliant slip device 40 that is made up of individual expandable segments 90, where the slit 92 between each adjacent segment 90 extends through from the end 47 of the compliant slip device 40 to the other end 46.
  • An end of each of the individual segments 90 can be inserted into a recess 57 in the annular surface 54 of the spacer ring 50.
  • An attachment means can secure the ends of the segments 90 in the recess 57.
  • the portion of the segments 90 secured in the recess 57 forms the rigid first body portion 82 of the compliant ring device 40.
  • the compliant region 98 is depicted as being the region between the surface 54 and the shoulders 42 (see Fig. 5C) of the third body portion of the segments 90.
  • the spacer ring 50 and the compliant slip device 40 form a single body.
  • the single body with spacer ring 50 and compliant device 40 combined will function similar to the compliant slip devices depicted in Figs. 4A - 5C .
  • expandable segments 90 can radially expand into engagement with an inside 15 of the tubing string 14 to secure the well tool 32 in the tubing string 14.
  • Figs. 7A - B depict a compliant slip device 40 that is made up of individual expandable segments 90, where the slit 92 between each adjacent segment 90 extends through from the end 47 of the compliant slip device 40 to the other end 46.
  • An end of each of the individual segments 90 can be secured to an annular surface 51 of the spacer ring 50 by an attachment means (e.g., fastener 45, threaded bolt and washer, screw, etc.) .
  • the portion of the segments 90 secured to the spacer ring 50 forms the rigid first body portion 82 of the compliant ring device 40.
  • the compliant region 98 is depicted as being the region between the attachment means and the shoulders 42 (see Fig. 5C) of the third body portion of the segments 90.
  • the spacer ring 50 and the compliant slip device 40 form a single body.
  • the single body with spacer ring 50 and compliant device 40 combined will function similar to the compliant slip devices depicted in Figs. 4A - 5C.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne un ensemble coin de retenue souple qui peut comprendre une bague d'espacement, une bague de coin et un dispositif coin de retenue souple, le dispositif coin de retenue pouvant comprendre un corps comprenant une première partie rigide, une deuxième partie souple et une troisième partie extensible, la troisième partie pouvant comprendre des segments extensibles qui sont circonférentiellement espacés les uns des autres avec une fente située entre des segments extensibles adjacents. L'invention concerne également un procédé de fixation d'un outil de puits dans une colonne de production à l'aide de l'ensemble coin de retenue souple, le procédé pouvant comprendre l'acheminement de l'outil de puits dans une colonne de production et l'extension de l'ensemble coin de retenue souple en appui sur la colonne de production, ce qui permet de fixer l'outil de puits dans la colonne de production.
PCT/US2015/024579 2015-04-06 2015-04-06 Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production WO2016163986A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US15/028,319 US20170260823A1 (en) 2015-04-06 2015-04-06 Compliant slip assembly for securing well tools in a tubing string
PCT/US2015/024579 WO2016163986A1 (fr) 2015-04-06 2015-04-06 Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2015/024579 WO2016163986A1 (fr) 2015-04-06 2015-04-06 Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production

Publications (1)

Publication Number Publication Date
WO2016163986A1 true WO2016163986A1 (fr) 2016-10-13

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PCT/US2015/024579 WO2016163986A1 (fr) 2015-04-06 2015-04-06 Ensemble coin de retenue souple pour la fixation d'outils de puits dans une colonne de production

Country Status (2)

Country Link
US (1) US20170260823A1 (fr)
WO (1) WO2016163986A1 (fr)

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JP6885518B1 (ja) * 2019-07-22 2021-06-16 三菱ケミカル株式会社 感光性着色樹脂組成物、硬化物、隔壁及び画像表示装置

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EP3347564B1 (fr) * 2015-09-08 2019-11-06 Parker Hannifin Corporation Ensemble bouchon provisoire soluble
USD806136S1 (en) * 2016-11-15 2017-12-26 Maverick Downhole Technologies Inc. Frac plug slip
CA3078610A1 (fr) * 2017-10-06 2019-04-11 G&H Diversified Manufacturing Lp Systemes et des procedes d'etancheisation d'un puits de forage
US20190153808A1 (en) * 2017-11-21 2019-05-23 Geodynamics, Inc. Plug slip ring with retaining mechanism and method
RU2706950C1 (ru) * 2019-05-31 2019-11-22 Общество с ограниченной ответственностью «Клеверенс Софт» Способ радиочастотной идентификации насосно-компрессорных труб
GB201913245D0 (en) * 2019-09-13 2019-10-30 Acoustic Data Ltd Coupling mechanism

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US5224540A (en) * 1990-04-26 1993-07-06 Halliburton Company Downhole tool apparatus with non-metallic components and methods of drilling thereof
US5678635A (en) * 1994-04-06 1997-10-21 Tiw Corporation Thru tubing bridge plug and method
US6536532B2 (en) * 2001-03-01 2003-03-25 Baker Hughes Incorporated Lock ring for pipe slip pick-up ring
US20030226668A1 (en) * 2002-06-07 2003-12-11 Zimmerman Patrick J. Anchoring and sealing system for a downhole tool
US20120133098A1 (en) * 2010-11-30 2012-05-31 Baker Hughes Incorporated Anti-extrusion backup system, packing element system having backup system, and method

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US5224540A (en) * 1990-04-26 1993-07-06 Halliburton Company Downhole tool apparatus with non-metallic components and methods of drilling thereof
US5678635A (en) * 1994-04-06 1997-10-21 Tiw Corporation Thru tubing bridge plug and method
US6536532B2 (en) * 2001-03-01 2003-03-25 Baker Hughes Incorporated Lock ring for pipe slip pick-up ring
US20030226668A1 (en) * 2002-06-07 2003-12-11 Zimmerman Patrick J. Anchoring and sealing system for a downhole tool
US20120133098A1 (en) * 2010-11-30 2012-05-31 Baker Hughes Incorporated Anti-extrusion backup system, packing element system having backup system, and method

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP6885518B1 (ja) * 2019-07-22 2021-06-16 三菱ケミカル株式会社 感光性着色樹脂組成物、硬化物、隔壁及び画像表示装置

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