WO2016065291A1 - Siège de bouchon expansible - Google Patents

Siège de bouchon expansible Download PDF

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Publication number
WO2016065291A1
WO2016065291A1 PCT/US2015/057168 US2015057168W WO2016065291A1 WO 2016065291 A1 WO2016065291 A1 WO 2016065291A1 US 2015057168 W US2015057168 W US 2015057168W WO 2016065291 A1 WO2016065291 A1 WO 2016065291A1
Authority
WO
WIPO (PCT)
Prior art keywords
slip ring
plug seat
wedge
wellbore
ring
Prior art date
Application number
PCT/US2015/057168
Other languages
English (en)
Inventor
Martin P. Coronado
Luis A. Garcia
Mark E. Plante
Rodney D. Bennett
Original Assignee
Hydrawell 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 Hydrawell Inc. filed Critical Hydrawell Inc.
Priority to EP15787867.9A priority Critical patent/EP3209855A1/fr
Publication of WO2016065291A1 publication Critical patent/WO2016065291A1/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
    • 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
    • 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
    • E21B33/129—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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures

Definitions

  • FIG. 1 illustrates two similar embodiments of an expandable plug seat, having a slip ring and two wedge rings, with Fig. 1 Al illustrating the first embodiment of a plug seat in unset configuration, Fig. 1 A2 illustrating the plug seat of Fig. 1A1 in set configuration, and Fig. 1 A3 illustrating a ball seated on the upper wedge ring of the set plug seat of Fig. 1A2 (thereby sealing the wellbore);
  • Fig. 1B1 illustrates a second embodiment of a plug seat in an unset configuration
  • Fig. 1B2 illustrates the plug seat of Fig. 1B1 in a set configuration
  • Fig. 1B3 illustrates a ball seated on the upper wedge ring of the set plug seat of Fig. 1B2 (thereby sealing the wellbore);
  • FIG. 2 illustrates an exemplary plug seat device made-up into a tool string having a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly), with Fig. 2A1 showing the top end view of the tool string when the plug seat is in its unset configuration, Fig. 2A2 showing the longitudinal cross-section view A-A of the tool string, and Fig. 2A3 showing a radial cross-sectional view B-B of the tool string in unset configuration; and Fig. 2B1 showing the top end view of the tool string when the plug seat device is in its set configuration, Fig. 2B2 showing the longitudinal cross-section view C-C of the tool string in its set configuration, and Fig. 2B3 showing a radial cross-sectional view D-D of the tool string in set configuration;
  • a wireline-conveyed power charge setting tool e.g. a wireline pressure setting assembly
  • FIG. 3 illustrates an alternative embodiment of a plug seat, having a slip ring and only one wedge ring/cone (along with additional elements), with Fig. 3A1 showing an exterior side view of the plug seat in unset configuration and Fig. 3 A2 showing a partial cutaway cross-section view of the unset plug seat, and Fig. 3B1 showing an exterior side view of the plug seat in set configuration and Fig. 3B2 showing a partial cutaway cross-section view of the set plug seat;
  • FIGs. 4A-D illustrate schematically a method of employing the plug seat downhole, with Fig. 4A showing pumping the plug seat to desired depth on wireline and using a setting tool to set the plug seat in place, Fig. 4B illustrates perforating the desired zone above the set plug seat, dropping and pumping a ball to seal the wellbore at the plug seat, and conducting fracturing operations in the well above the set plug seat, Fig. 4C shows how this process may be repeated multiple times until all desired zones of the well have been fractured, and Fig. 4D illustrates how over time the dissolvable ball may dissolve to open the completion liner (e.g. cased wellbore) to production;
  • completion liner e.g. cased wellbore
  • FIG. 5 illustrates yet another alternative embodiment of a plug seat, having a slip ring and two wedge rings similar to Fig. 1 (but for example, optionally without an external seal on the slip ring), with Fig. 5A1 showing a partial cut-away cross-section view of an exemplary tool string with the plug seat in unset configuration, Fig. 5A2 showing a cross-section of the tool string of Fig. 5A1, Fig. 5 A3 showing a side view of the unset plug seat of Fig. 5A1, and Fig. 5A4 showing a cross- section view of the unset plug seat of Fig. 5 A3; and Fig.
  • FIG. 5B1 showing a partial cut-away cross- section view of the exemplary tool string with the plug seat in set configuration
  • Fig. 5B2 showing a side view of the set plug seat of Fig. 5B1 (after application of sufficient force on the wedge rings deforms the slip ring outward into set configuration)
  • Fig. 5B3 showing a cross-section view of the set plug seat of Fig. 5B2
  • Fig. 5B4 showing a cross-section view of the set plug seat of Fig. 5B3 with a ball seated on the upper wedge ring of the plug seat (thereby blocking fluid flow through the longitudinal bore of the plug seat and/or the cased wellbore in which the plug seat is set/affixed)
  • FIG. 6 illustrates still another alternative embodiment of a plug seat, having a slip ring and only one wedge ring, with Fig. 6A1 showing a partial cut-away cross-section view of an exemplary tool string with a plug seat in the unset configuration, Fig. 6A2 shows a side view of the unset plug seat of Fig. 6A1, and Fig. 6A3 shows a cross-section of the unset plug seat of Fig. 6A2; and Fig. 6B1 showing a cross-section of the set plug seat (after application of sufficient force on the wedge ring deforms the slip ring outward into set configuration), and Fig. 6B2 shows a cross-section of the set plug seat of Fig. 6B1 with a ball seated on the wedge ring of the plug seat (thereby blocking fluid flow through the longitudinal bore of the plug seat and/or the cased wellbore in which the plug seat is set/affixed).
  • the term “ring” shall, when used in reference to an element for use within a well or tool string for example, typically mean that the element has a hole, opening, or longitudinal bore therethrough (for example, of the sort which might allow fluid flow through the element), and typically such bore would be located approximately along the central (longitudinal) axis of the element;
  • component or feature may,” “can,” “could,” “should,” “would,” “preferably,” “possibly,” “typically,” “optionally,” “for example,” “often,” or “might” (or other such language) be included or have a characteristic, that particular component or feature is not required to be included or to have the characteristic. Such component or feature may be optionally included in some embodiments, or it may be excluded.
  • Embodiments may relate generally to methods and devices for setting a plug seat within a downhole well, for example in advance of fracing operations.
  • the disclosed expandable plug seat embodiments typically include an expandable slip ring (which in some embodiments may optionally have an elastomeric seal on its exterior) and one or more wedge rings (and in some embodiments, the plug seat may consist essentially of or consist only of a slip ring and one or more wedge rings).
  • typical embodiments might include dual wedge rings, with an upper wedge ring located above the slip ring and a lower wedge ring located below the slip ring. In other embodiments, a single wedge ring might be located with respect to (for example, above) the slip ring.
  • each of the one or more wedge rings thereby deforming the expandable slip ring and driving it radially outward and into contact with the casing in the wellbore (due to the interaction of the wedge-like shape of the one or more wedge rings with the inner (radial) surface of the slip ring).
  • deformation of the slip ring may be plastic and/or elastic (and most typically there would be plastic deformation of the slip ring).
  • the expandable plug seat may be used with a dissolvable ball (which might be either dissolvable metal or dissolvable polymer), which can be pumped to seat onto the plug seat device (for example, directly on the upper wedge ring).
  • a dissolvable ball which might be either dissolvable metal or dissolvable polymer
  • the plug seat device for example, directly on the upper wedge ring.
  • hydraulic fracturing operations can commence.
  • the ball may dissolve, allowing access to the wellbore without the need to drill the plug.
  • one or more element of the plug seat may also dissolve, providing additional radial space in the well (for example, for future production).
  • the plug seat device might comprise an expandable (for example, solid) slip ring (which optionally may have an external elastomeric seal), wherein the expandable slip ring is operable to expand by deforming (plastically and/or elastically) radially outward (upon application of sufficient force on its inner diameter); and one or more wedge rings (for example, operable to slide longitudinally and) located with respect to the slip ring so that application of sufficient longitudinal force on the wedge rings operates to drive the slip ring radially outward (e.g. causing the deformation of the slip ring).
  • an expandable slip ring which optionally may have an external elastomeric seal
  • the expandable slip ring is operable to expand by deforming (plastically and/or elastically) radially outward (upon application of sufficient force on its inner diameter)
  • one or more wedge rings for example, operable to slide longitudinally and located with respect to the slip ring so that application of sufficient longitudinal force on the wedge rings operates to drive the slip ring radially outward (e.
  • each wedge ring would comprise a wedge-like shape (for example, with the outer diameter of the wedge ring at one end (typically the end farther away from the slip ring in the unset configuration) being larger than the outer diameter of the wedge ring at the opposite end (typically the end closer to the slip ring in the unset configuration)) having an angled vertex/outer surface ranging from about 5-10 degrees (or alternatively 3-20 degrees), for example.
  • the slip ring typically would be operable to deform (plastically and/or elastically) radially outward upon application of force from the wedge rings (for example, when sufficient longitudinal force is applied to the one or more wedge rings, driving the one or more wedge rings further into the slip ring, and thereby driving the slip ring radially outward due to the wedge-shape of the wedge rings).
  • the expandable plug seat typically would have an (initial) unset configuration and a set configuration (e.g.
  • the slip ring typically has an initial outer diameter that is less than the inner diameter of the casing and/or wellbore (for example, allowing the plug seat device to be run downhole); one wedge ring (e.g. the upper wedge ring) is typically located above the slip ring; and optionally one wedge ring (e.g.
  • the lower wedge ring may be located below the slip ring, for example with (only) the vertex of each wedge ring initially being located within (e.g. radially inward of and contacting the inner diameter/surface of) the slip ring (such that the remainder of the wedge rings typically would be located outside the slip ring and would not contact the slip ring in the unset configuration). So, the plug seat would be transitioned from its unset configuration to its set configuration by application of sufficient longitudinal force on the one or more wedge rings (for example, sliding the wedge rings longitudinally towards each other and/or inward of the slip ring - for example, with more of the wedge ring(s) located within the slip ring).
  • the one or more wedge rings would have been driven (and are located) further within the slip ring (for example, with the upper wedge ring being driven downward into the slip ring and the lower wedge ring being driven upward into the slip ring), thereby driving the slip ring radially outward via deformation (plastic and/or elastic) of the slip ring until the outer diameter of the slip ring contacts the inner diameter of the casing and/or wellbore with sufficient force to hold the slip ring in place during fracing operations (e.g. the outer diameter of the slip ring in the set configuration is approximately equal to and contacts the inner diameter of the casing and/or wellbore).
  • the slip ring may be set (e.g.
  • the slip ring is configured so that it is operable to transition from its unset position/shape/size (with an outer diameter less than the inner diameter of the cased wellbore, for example) to its set position/shape/size (with outer diameter equal to the inner diameter of the cased wellbore, for example).
  • the slip ring may optionally have a plurality of anchoring teeth on its outer surface, configured to more securely attach the slip ring in place on the inner surface of the cased wellbore (in the set configuration), for example with the teeth operable/configured to penetrate the casing slightly upon setting of the plug seat (for example, penetrating about 0.010-0.030 inches).
  • the slip ring may optionally also have a plurality of longitudinal slots (which typically might not penetrate all the way through the slip ring, but merely would be indentations forming a thinner wall cross- section at locations in the slip ring - although in other embodiments, the slots could form openings in the slip ring) which may be located radially around the circumference of (e.g.
  • each such longitudinal slot might have a width of about 0.2S inches, a length of about 2.17 inches, and a depth to not fully penetrate the slip ring, but rather to leave a thin web (for example about 0.030 inches thick).
  • An exemplary embodiment might have about 15 such slots spaced evenly around the exterior circumference of the slip ring.
  • the slip ring may have an elastomeric (or other) seal element located on its outer/exterior surface, in other embodiments the slip ring may be configured to effectively form a seal when driven into contact with the cased wellbore (e.g. an effective seal might be formed without the use of any such separate seal element).
  • the plug seat device does not contain any additional retention elements (such as a body lock ring or mandrel) beyond the slip ring and/or wedge rings (so for example, the plug seat may consist essentially of or consist of only the slip ring and one or more wedge rings). Additionally, typically the plug seat device would not contain a separate ball seat (e.g., the ball could be landed directly on the upper wedge ring). So for example, the plug seat of some embodiments might consist essentially of (or consist of) only the slip ring and one or more wedge rings.
  • the slip ring may comprise an outer surface, which may comprise a plurality of anchoring teeth/barbs/ridges in some embodiments for securing/attaching/anchoring the slip ring in place on the inner surface of the casing and/or wellbore (providing a better lock/grip than friction alone).
  • the optional elastomeric seal typically located on the outer/exterior surface of the slip ring in embodiments having such a seal typically would be configured/operable to effectively seal fluid flow about the exterior of the plug seat device when set in place within the casing (although in other embodiments, such an effective seal might be formed by contact of the slip ring body itself against the cased wellbore, without any need for a separate seal element).
  • the optional seal diameter would be slightly larger than the outer diameter of the slip ring (for example, larger than the slip teeth diameter) to allow for compression when set.
  • Such a seal might be rated for 10,000 psi differential pressure at 350 degrees Fahrenheit.
  • Exemplary seal materials might be either Nitrile or Aflas.
  • the plug seat device might be operable or configured to work in conjunction with a sealing ball/plug.
  • a sealing ball/plug Such a ball might be formed of a dissolvable material (which might be metallic or polymeric material operable to dissolve over time (for example, approximately 1-5 days) under exposure to elevated temperature (for example a range of approximately 150-250 degrees Fahrenheit) and either brine (for example KCL brine) or acid (for example approximately 2-5 pH range)).
  • a dissolvable material might be Terv Alloy or similar materials sold by Terves, Inc.
  • Another example of such dissolvable material might be polymer from Bubbletight LLC.
  • the slip ring and/or one or more wedge rings in the set configuration might be configured to have an inner diameter sufficiently large to allow for access to the wellbore via tubing or wireline (such that they do not need to be drilled out to allow for production of the well).
  • the one or more wedge rings and/or the slip ring of the plug seat might also be formed of such dissolvable material (e.g. material operable to dissolve over time (for example, approximately 1-5 days) under exposure to elevated temperature (for example a range of approximately 150-250 degrees Fahrenheit) and either brine (for example KCL brine) or acid (for example approximately 2-5 pH range)).
  • the one or more wedge rings and/or slip ring might be formed of the same dissolvable material as the sealing ball/plug. This would allow the plugged wellbore to open (after the timeframe needed for fracing, for example) without the need for drilling.
  • the plug seat device may be configured/operable to be made-up into a tool string with a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly) and/or a perforating gun assembly.
  • a tool string may allow the plug seat to be set and the wellbore to be perforated in one wireline trip downhole (e.g. prior to fracturing the zone).
  • FIG. 1A illustrates a first embodiment of a plug seat device 10
  • Fig. IB illustrates a second, similar embodiment of a plug seat device
  • Fig. 1 Al illustrates an exemplary plug seat device 10 in its unset configuration (e.g. its initial configuration, allowing it to be run downhole into position within the wellbore).
  • the plug seat device of Fig. 1 Al has a slip ring 20 and two wedge rings 30 and 40.
  • the slip ring 20 of Fig. 1 Al is configured as a solid ring operable to deform (e.g.
  • the slip ring 20 has an outer diameter that is less than the inner diameter of the casing/wellbore 5 (to provide sufficient clearance so that the plug seat can be run downhole).
  • the wedge rings 30, 40 each of which may be operable to slide longitudinally upon application of sufficient longitudinal force
  • the angled surfaces of the wedge rings 30, 40 would drive the slip ring 20 radially outward and into contact with the wellbore/casing 5.
  • the slip ring 20 of Fig. 1 Al typically has an elastomeric seal 22 (although this may be optional) about its outer/exterior surface (for example, extending circumferentially about the exterior of the slip ring), and the elastomeric seal 22 is configured/capable/operable of providing an effective seal to prevent fluid flow about the exterior of the slip ring 20 in its set configuration.
  • the slip ring of Fig. 1 Al typically has an elastomeric seal 22 (although this may be optional) about its outer/exterior surface (for example, extending circumferentially about the exterior of the slip ring), and the elastomeric seal 22 is configured/capable/operable of providing an effective seal to prevent fluid flow about the exterior of the slip ring 20 in its set configuration.
  • 1A1 typically would have a plurality of gripping or anchoring elements 25 (typically termed teeth) on its exterior surface (for example, teeth, barbs, or ridges operable to bite/dig into the inner diameter surface of the casing/wellbore 5 when the plug seat is set, to provide a more effective hold to lock the set plug seat in place).
  • teeth typically termed teeth
  • gripping or anchoring elements 25 typically termed teeth
  • ridges operable to bite/dig into the inner diameter surface of the casing/wellbore 5 when the plug seat is set, to provide a more effective hold to lock the set plug seat in place.
  • the two wedge rings 30 and 40 each typically have an angle of about 10 degrees (so for example, the outer surface of the wedge rings might have an angle of about 10 degrees with respect to a line parallel to the centerline of the plug seat device).
  • one wedge ring would be located on either side of the slip ring 20 (for example, with an upper wedge ring 30 located above the slip ring 20, and the lower wedge ring 40 being located below the slip ring 20), and typically only the vertex 32, 42 of the wedge rings would be located initially within the slip ring 20 and contacting the inner surface of the slip ring (e.g.
  • the remainder of the wedge rings 30, 40 would initially be located outside the slip ring, for example longitudinally).
  • the wedge rings 30, 40 would have an outer diameter that at their furthest end is less than the inner diameter of the casing/wellbore 5 (to again ensure that the plug seat device as a whole has an outer diameter that is less than the inner diameter of the casing/wellbore 5, so that there is sufficient clearance to allow for running of the plug seat device downhole).
  • the outer diameter (of the far end of) the wedge rings 30, 40 would typically be spaced away from the inner diameter of the casing/wellbore 5 about a distance less than the thickness of the slip ring 20).
  • the wedge rings 30, 40 would typically be formed of a material which is sufficiently strong to drive the slip ring outward (under application of sufficient longitudinal force), such as AISI 4140 material with 110 minimum yield strength.
  • Fig. 1A2 illustrates the same plug seat device from Fig. 1A1 in its set configuration (e.g. after application of sufficient longitudinal force on the wedge rings, to drive the slip ring Atty Docket No.: 4466-00403 radially outward and into contact with the casing/wellbore, thereby fixing the plug seat 10 into position in the well).
  • Longitudinal force typically would be applied to the top of the upper wedge ring 30 and to the bottom of the lower wedge ring 40, thereby driving the wedge rings closer together and further into the slip ring 20.
  • the setting longitudinal force for some embodiments might be approximately 10,000-30,000 lbs.F.
  • Fig. 1A2 which shows the plug seat in its set configuration
  • the wedge rings 30, 40 are closer together, with more of the wedge rings 30, 40 length located within the slip ring 20.
  • the slip ring 20 of Fig. 1A2 has a larger outer diameter, which is approximately equal to the inner diameter of the casing/wellbore 5.
  • Fig. 1 A3 shows how the open longitudinal bore of the set plug seat device 10 may be sealed by seating a ball 50 onto the upper wedge ring 30. This would typically be done in advance of fracturing operations uphole of the plug seat 10.
  • the ball 50 would typically have a diameter larger than the inner diameter of the wedge ring 30, and would typically seat directly onto the upper wedge ring 30.
  • the ball 50 would be formed of dissolvable materials.
  • the ball 50 might be formed of dissolvable metallic material operable to dissolve over time (for example, approximately 1-5 days) under exposure to elevated temperature (for example a range of approximately 150-250 degrees Fahrenheit) and either brine (for example KCL brine) or acid (for example approximately 2-5 pH range).
  • the ball might be made of a dissolvable polymer material, such as made by Bubbletight LLC for example.
  • the ball might have a protective coating, for example to delay dissolution of the ball (although in other embodiments, the well chemistry might be used (perhaps along with a protective coating) to delay or control the timing of dissolution).
  • the use of such a dissolvable ball 50 might allow for the plug seat 10 to be temporarily sealed by a ball, but to be operable to open at a later time without the need for drilling.
  • the wedge rings 30, 40 and/or slip ring 20 might also be formed of similar dissolvable materials (which might allow for a larger bore without the need for drilling).
  • Fig. IB illustrates a similar plug seat 10, having wedge rings 30, 40 with an angle of about 5 degrees (e.g. the outer surface of the wedge rings would have an angle of about 5 degrees with respect to a line parallel to the centerline of the plug seat 10).
  • Fig. 1B1 shows the plug seat in unset configuration
  • Fig. 1B2 shows the plug seat in set configuration
  • Fig. 1B3 shows the plug seat when sealed by a ball 50.
  • the wedge rings 30, 40 may be driven together until their vertexes contact. It should be understood that sufficient longitudinal force applied to the wedge rings may effectively set the slip ring in the casing/wellbore, as discussed above.
  • the plug seat 10 may be made-up into a tool string having a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly, such as Baker Style #20 WL Setting Tool), for applying the longitudinal force required to set the plug seat 10 in place in the casing/wellbore.
  • a wireline-conveyed power charge setting tool e.g. a wireline pressure setting assembly, such as Baker Style #20 WL Setting Tool
  • Fig. 2 illustrates such an exemplary tool string, with Fig. 2 A showing the tool string when the plug seat 10 is in the unset configuration, and Fig. 2B showing the tool string when the plug seat 10 is in the set configuration.
  • Fig. 2A1 shows a top side view of the tool string in unset configuration, while Fig.
  • FIG. 2A2 shows a longitudinal cross- sectional view A-A (showing the plug seat device 10 in unset configuration and in place in line with the setting tool 60), and Fig. 2A3 shows a radial cross-sectional view B-B.
  • Fig. 2B1 shows a top side view of the tool string in set configuration
  • Fig. 2B2 shows a longitudinal cross- sectional view C-C (showing the plug seat device 10 in set configuration and in place in line with the setting tool 60)
  • Fig. 2B3 shows a radial cross-sectional view D-D.
  • the tool string may also include a perforating gun (not shown, but for example, located above the plug seat 10).
  • Such a tool string configuration might allow setting of the plug seat and perforating of the well using only a single trip downhole (prior to fracturing the zone). Then, for example, a dissolvable ball might be seated on the plug seat to allow for fracing operations (for example, during the time before the ball and/or wedge rings dissolve).
  • Fig. 3 illustrates an alternative embodiment of a plug seat.
  • the plug seat of Fig. 3 comprises a dissolvable mandrel or body, a dissolvable tapered cone/wedge ring (similar to that discussed above), a dissolvable lock ring, and/or a solid expandable slip ring (similar to the slip ring discussed above) having an inner seal and an outer seal (although such seals may be optional, with one or both being omitted from some embodiments).
  • the dissolvable materials might be the same or similar to those discussed above, for example.
  • the wedge ring/cone would typically have a wedge-like portion having an angled outer surface (for example, ranging from about 3-20 degrees).
  • the mandrel has a flow-through passage, which may allow flow bypass prior to fracturing operations.
  • the mandrel also features a ball seat on the uphole end.
  • the mandrel would also comprise an angled outer surface portion located (below the slip ring) and oriented to work in conjunction with the wedge ring (when sufficient longitudinal force is applied to the wedge ring) to drive the slip ring radially outward during setting of the plug seat (e.g. causing plastic deformation of the slip ring as it moves from the unset position to the set position).
  • the angled outer surface portion of the mandrel typically might match the angle of the wedge ring and/or be 3-20 degrees.
  • the plug seat of Fig. 3 has an initial, unset configuration, and a set configuration.
  • Figs. 3A1-2 show the plug seat in its unset configuration
  • Fig. 3B1-2 show the plug seat in its set configuration.
  • a longitudinal force would be applied to the dissolvable lock ring and/or tapered cone/wedge ring while the mandrel is held in place. The force would serve to deform (e.g. plastically and/or elastically) the expandable solid slip ring, driving it radially outward until it contacts the inner diameter of the casing/wellbore.
  • a dissolvable ball (which, for example, might be formed of the same dissolvable material as the dissolvable elements of the plug seat) may be dropped and pumped to seat on the mandrel (e.g. the ball seat) of the plug seat, to allow for fracturing operations.
  • the dissolvable elements of the plug seat (and the ball) will dissolve, for example leaving only the slip ring and/or seals behind (which should not inhibit production flow and typically would have a sufficiently large inner diameter to allow for access to the wellbore via tubing and/or wireline).
  • the slip ring might be formed of dissolvable material (for example, similar to that described above), such that only the elastomeric seals (if any) might be left un-dissolved in the wellbore.
  • the ball and/or dissolvable elements of the plug seat device might have a protective coating, for example to delay dissolution (although in other embodiments, the well chemistry might be used (perhaps along with a protective coating) to delay or control the timing of dissolution).
  • Figs. 5A1-4 illustrate an alternative embodiment of a plug seat (similar to that shown in Figs. 1A-1B for example) in unset configuration, while Figs. 5B1-4 illustrate the same embodiment in set configuration.
  • Figs. 5A1 and 5A2 illustrate the plug seat 510 within an exemplary tool string (e.g. the plug seat may be removably coupled to the tool string, for example with a wireline-conveyed power charge setting tool), with Fig, 5A1 showing a partial cut-away cross-section view of the tool string and Fig. 5 A2 showing a full cross-section of the tool string (in unset configuration).
  • FIG. 5 A3 illustrates (in a side view) just the plug seat 510 in unset configuration
  • Fig. 5A4 illustrates the same unset plug seat 510 via cross-section view
  • the plug seat 510 has two wedge rings 530 and 540 configured to interact (via longitudinal sliding) with the slip ring 520 (typically with one wedge ring 530 located above the slip ring 520, and one wedge ring 540 located below the slip ring 520).
  • the plug seat 510 has two wedge rings 530 and 540 configured to interact (via longitudinal sliding) with the slip ring 520 (typically with one wedge ring 530 located above the slip ring 520, and one wedge ring 540 located below the slip ring 520).
  • each wedge ring 530, 540 is initially located within the slip ring 520, but the wedge rings 530, 540 are configured to slide further into the slip ring 520 upon application of sufficient longitudinal force (e.g. shifting from unset to set configuration).
  • the slip ring 520 in this unset configuration has an outer diameter which is configured to be less than the inner diameter of the cased wellbore (for which the plug seat is intended to be used), and is operable/configured to deform (plastically and/or elastically) under application of force from the wedge rings 530, 540 (in order to shift outward from the unset to the set configuration/position).
  • the wedge rings 530, 540 also have a maximum outer diameter which is less than the inner diameter of the cased wellbore (although typically the difference between the maximum outer diameter of the wedge rings 530, 540 and the inner diameter of the cased wellbore is less than or equal to the thickness of the slip ring, for example after deformation to the set position).
  • the slip ring 520 comprises a plurality of teeth 525 on its outer/exterior surface, typically located about the circumference of the slip ring outer surface. While the teeth 525 may be oriented in various ways (e.g. to form a secure hold onto the cased wellbore), in Fig. 5A3 the teeth on the upper portion of the slip ring 520 face one direction (for example, angled downward), while the teeth on the lower portion of the slip ring 520 may face another direction (for example, angled upward).
  • the slip ring 520 of Fig. 5 A3 also comprises a plurality of longitudinal slots 527 located evenly about its outer surface circumference. For example, in Fig.
  • each slot 527 typically having a width of about 0.25 inches, a length of about 2.17 inches, and a depth to not fully penetrate the slip ring, but rather leave a thin web (for example about 0.030 inches thick).
  • the slip ring 520 is typically made of a material operable to deform from unset to set configuration upon application of sufficient force (radially) via the wedge rings 530, 540.
  • the wedge rings 530, 540 and/or the slip ring 520 may be formed of dissolvable material (as discussed above).
  • the wedge rings and/or slip ring are not dissolvable (for example, if only a dissolvable ball is used to close the bore), then they (e.g. one or both) may instead have a bore (e.g.
  • the wedge rings 530, 540 typically have a wedge-like shape (for example, in cross-section), with the outer surface having an angle (for example, with respect to a line parallel to the longitudinal bore centerline) ranging from about 3-20 degrees (or for example, alternately 5-20, 5-10, or 10-20 degrees).
  • the seat plug of Fig. 5 may consist essentially of or consist of only the slip ring 520 and wedge rings 530, 540.
  • the wedge rings 530, 540 Upon application of sufficient longitudinal force on the wedge rings 530, 540 (for example, with the setting tool pressing down on the upper wedge ring 530 directly, while the lower wedge ring 540 is pressed up against by an insert 508 which interacts with the setting tool in the tool string to transmit upward longitudinal force to the lower wedge ring), the wedge rings 530, 540 move (e.g. slide longitudinally) further into the slip ring (for example, towards each other), with their wedge-like shape driving the slip ring 520 to deform (plastically and/or elastically) outward to the set configuration/position as shown in Figs.
  • FIG. 5B1 illustrates in partial cross-section the plug seat 510 (in set configuration) in place within a tool string
  • Fig. 5B2 shows just the plug seat 510 in set configuration from a side view
  • Fig. 5B3 shows the same set plug seat 510 in cross-section
  • Fig. 5B4 shows the set plug seat 510 with a ball 550 (typically dissolvable) seated on the upper wedge ring 530 to close/seal the bore (for example, in preparation for tracing).
  • a ball 550 typically dissolvable
  • the wedge rings 530, 540 have been driven closer together and are substantially located within the slip ring 520 (e.g. the gap between the set wedge rings is much smaller than in the unset configuration shown in Fig. 5A4 for example).
  • the slip ring 520 of Fig. 5B3 in the set configuration typically would have an outer diameter approximately equal to the inner diameter of the cased wellbore at issue.
  • embodiments may optionally include a shear ring or tab (for example, attached to the slip ring and/or the lower wedge ring) in the unset configuration of Fig. 5A1, which may be operable/configured to be sheared once the setting tool provides the required setting force.
  • Figs. 6A1-3 illustrate another alternative embodiment of a plug seat (similar to that shown in Figs 1A-B and/or Fig. 3 for example) in unset configuration, while Figs. 6B1-2 illustrate the same embodiment in set configuration.
  • Fig. 6A1 illustrates the plug seat 610 within an exemplary tool string (e.g. the plug seat may be removably coupled to the tool string, for example with a wireline-conveyed power charge setting tool), with Fig. 6A1 showing a partial cross-section view of the tool string (in unset configuration).
  • Fig. 6A2 illustrates (in a side view) just the plug seat 610 in unset configuration, while Fig.
  • FIG. 6 A3 illustrates the same unset plug seat 610 via cross- section view. So as clearly shown in Figs. 6A2-3, the plug seat 610 has only one wedge ring 630 (typically located above the slip ring 620), which is configured to interact (via longitudinal sliding) with the slip ring 620. In other words, in Fig. 6A3, only the vertex of the wedge ring 630 is initially located within the slip ring 620 (in unset configuration), but the wedge ring 630 is configured to slide further into the slip ring 620 upon application of sufficient longitudinal force (e.g. shifting from unset to set configuration).
  • sufficient longitudinal force e.g. shifting from unset to set configuration
  • the slip ring 620 in this unset configuration has an outer diameter which is configured to be less than the inner diameter of the cased wellbore (for which the plug seat is intended to be used), and is operable/configured to deform (plastically and/or elastically) under application of force from the wedge ring 630 (in order to shift outward from the unset to the set configuration/position).
  • the wedge ring 630 also has a maximum outer diameter which is less than the inner diameter of the cased wellbore (although typically the difference between the maximum outer diameter of the wedge ring 630 and the inner diameter of the cased wellbore is less than or equal to the thickness of the slip ring, for example after deformation to the set position).
  • the slip ring comprises a plurality of teeth 625 on its outer/exterior surface, typically located about the circumference of the slip ring outer surface. While the teeth 625 may be oriented in various ways (e.g. to form a secure hold onto the cased wellbore), in Fig. 6A3 the teeth all face one direction (for example, angled downward).
  • the slip ring 620 of Fig. 6A3 also comprises a plurality of longitudinal slots 627 located evenly about its outer surface circumference. For example, in Fig.
  • each slot typically having a width of about 0.25 inches and a length of about 2.17 inches (and some embodiments having a slot depth penetrating the slip ring, while other embodiments might have a depth to not fully penetrate the slip ring, but leaving a thin web (for example about 0.030 inches)).
  • the slip ring 620 is typically made of a material operable to deform from unset to set configuration upon application of sufficient force (radially) via the wedge ring 630. And typically, the wedge ring 630 and/or the slip ring 620 may be formed of dissolvable material (as discussed above). On the other hand, if the wedge ring and/or slip ring are not dissolvable (for example, if only a dissolvable ball is used to close the bore), then they (e.g. one or both) may instead have a bore (e.g.
  • the wedge ring 630 typically has a wedge-like shape (for example, in cross-section), with the outer surface having an angle (for example, with respect to a line parallel to the longitudinal bore centerline) ranging from about 3- 20 degrees (or for example alternately, 5-20, 5-10, or 10-20 degrees).
  • the seat plug of Fig. 6 may consist essentially of or consist of only the slip ring 620 and wedge ring 630.
  • the wedge ring 630 moves (e.g. slide longitudinally) further into the slip ring (for example, with most of the length of the wedge ring located within the slip ring), with the wedge-like shape driving the slip ring 620 to deform (plastically and/or elastically) outward to the set configuration/position as shown in Figs. 6B1-2 for example (when its outer diameter is configured to be approximately equal to the inner diameter of the cased wellbore, providing a secure attachment of the plug seat to the cased wellbore, as discussed above).
  • Fig. 6B1-2 when its outer diameter is configured to be approximately equal to the inner diameter of the cased wellbore, providing a secure attachment of the plug seat to the cased wellbore, as discussed above).
  • FIG. 6B1 illustrates in cross-section just the plug seat 610 (in set configuration), while Fig. 6B2 shows the set plug seat 610 with a ball 650 (typically dissolvable) seated on the wedge ring 630 to close/seal the bore (for example, in preparation for fracing).
  • the wedge ring 630 has been driven farther into the slip ring and is substantially located within the slip ring 620.
  • the slip ring 620 of Fig. 6B1 (in the set configuration) typically would have an outer diameter approximately equal to the inner diameter of the cased wellbore at issue.
  • embodiments may optionally include a shear ring or tab (for example, attached to the slip ring) in the unset configuration of Fig. 5A1, which may be operable/configured to be sheared once the setting tool provides the required setting force. This may limit the amount of force applied to the plug seat, and may also allow for the plug seat to disconnect from the setting tool once set.
  • a shear ring or tab for example, attached to the slip ring
  • FIG. 5A1 may be operable/configured to be sheared once the setting tool provides the required setting force. This may limit the amount of force applied to the plug seat, and may also allow for the plug seat to disconnect from the setting tool once set.
  • plug seat device embodiments described above may allow for an improved method of fracturing a well, especially for example when used in conjunction with a dissolvable ball/plug.
  • a method of performing downhole operations (such as fracing) within a (typically cased) wellbore uses an expandable plug seat (which, for example, might include a slip ring and one or more wedge rings located with respect to the slip ring so that application of sufficient longitudinal force on the wedge rings operates to drive the slip ring radially outward) and includes the step of applying a longitudinal force onto the one or more wedge rings (thereby driving the wedge rings towards one another and/or deeper into the slip ring), thereby deforming (e.g.
  • the longitudinal force may be applied to the wedge rings by a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly).
  • a wireline-conveyed power charge setting tool e.g. a wireline pressure setting assembly.
  • the plug seat might not contain any additional retention elements (such as body lock ring or mandrel) beyond the slip ring and/or wedge ring(s). Additionally, the plug seat typically would not contain a separate ball seat; rather, the ball would be landed directly on the upper wedge ring. So in some embodiments, the plug seat may consist essentially of (or consist of) only the slip ring and one or more wedge rings.
  • the method may further comprise the step of positioning the plug seat within the wellbore (i.e. locating the plug at the proper location downhole within the wellbore for sealing of the wellbore for fracturing of a zone).
  • the plug seat may be run downhole in conjunction with a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly) and/or a perforating gun assembly (e.g. all three would be run downhole together at the same time). This may allow for more efficient setting of the plug seat and perforating of the well (reducing the number of separate trips run downhole).
  • such a method would include making-up a tool string comprising the plug seat, a wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly), and/or a perforating gun assembly, and then positioning the plug seat in the wellbore, setting the plug seat using the wireline-conveyed power charge setting tool (e.g. a wireline pressure setting assembly), and perforating the well casing, all in a single trip downhole.
  • the plug seat Once the plug seat has been set in the wellbore and the well/casing has been perforated, the wellbore can be sealed to allow for fracturing of the well upstream of the plug seat.
  • the wedge rings may comprise at least an upper wedge ring located above the slip ring, and the method may further comprise landing (e.g. pumping) a dissolvable ball/plug onto the upper wedge ring (to isolate/seal the downstream section of the well).
  • the ball typically would land directly on the upper wedge ring, without a separate ball seat.
  • the ball may be formed of dissolvable material (operable to dissolve over time (for example, approximately 1-5 days) under exposure to elevated temperature (for example a range of approximately 150-250 degrees Fahrenheit) and either brine (for example KCL brine) or acid (for example approximately 2- 5 pH range).
  • the plug seat (or at least portions of the plug seat, such as the one or more wedge rings and/or the seal ring) would be formed of dissolvable material (for example, operable to dissolve over time (for example, approximately 1-5 days) under exposure to elevated temperature (for example a range of approximately 150-250 degrees Fahrenheit) and either brine (for example KCL brine) or acid (for example approximately 2- 5 pH range).
  • exemplary materials might be TervAlloy or similar materials sold by Terves, Inc., or dissolvable polymeric material by Bubbletight LLC.
  • the slip ring and/or one or more wedge rings may be formed of the same dissolvable material as the ball (or in some embodiments, the wedge ring(s) and/or slip ring may be dissolvable, while the ball might not be).
  • the method might include fracturing a zone of the well above the set and sealed plug seat (e.g. with the ball in place on the upper wedge ring).
  • the wellbore in question would comprise a horizontal portion (e.g. a horizontal well), having a toe and a heel.
  • the initial plug seat is set towards the toe of the horizontal portion of the well (e.g. farthest downhole).
  • the process typically would be repeated one or more times from the toe of the horizontal portion of the well towards the heel.
  • the ball and/or plug seat would dissolve (over about 1-5 days, due to exposure to well conditions (e.g. elevated temperature, acid and/or brine), without the need for drilling to open the wellbore).
  • well conditions e.g. elevated temperature, acid and/or brine
  • the wellbore might be accessed downstream of the location of the set plug seat(s) via tubing and/or wireline without drilling the ball and/or plug seat (due to the dissolvable nature of the ball and/or plug seat), allowing production of the well without drilling the ball and/or plug seat.
  • FIG. 4A a plug seat 410 is pumped to the desired depth on a wireline, and is set in place using a setting tool. Typically, this initial plug seat 410 would be set in place towards the toe 401 of the horizontal well 402. And typically, the plug seat 410 would be set in place by application of longitudinal force upon the wedge ring(s) of the plug seat 410, thereby driving the slip ring of the plug seat 410 radially outward and into contact with the casing/wellbore 405. Once the plug seat has been set, the well zone would be perforated above the set plug seat (as shown in Fig. 4B).
  • a single tool string would be made-up having the plug seat 410, a setting tool (not shown), and a perforating gun (not shown). This would allow the plug seat 410 to be set and the well zone to be perforated in a single trip downhole.
  • a dissolvable ball 450 might be dropped and pumped downhole until it is seated on the plug seat 410 (as shown in Fig. 4B).
  • fracturing operations may be performed in the desired zone above the plug seat 410 (as shown in Fig. 4B). This process may be repeated until all desired zones have been fractured (e.g. placing multiple plug seats, typically proceeding from the toe 401 towards the heel 402 of the horizontal well).
  • FIG. 4C shows an exemplary well, in which a plurality of plug seats have been set in place and sealed (via dissolvable ball), and fracturing operations have occurred in a zone above each of the plug seats.
  • the plugs e.g. the ball/plug and/or wedge ring(s)
  • the plugs would disappear after a predetermined period of time (dissolving under well conditions, as shown for example in Fig. 4D).
  • the ball and wedge ring(s) would be formed of dissolvable material, such that after the predetermined period of time, only the slip ring (and any elastomeric seal on the slip ring) of each plug seat would remain in place in the well (although in other embodiments, only the ball might be dissolvable).
  • the inner diameter of the set slip ring would be sufficiently large that it would not interfere with production of the well (for example, allowing passage of tubing and/or wireline devices).
  • the slip ring (as well as the ball and wedge ring(s)) might be formed of dissolvable material (for example, to provide an even larger longitudinal bore).
  • an expandable plug seat device operable to be set within casing for a wellbore, comprising: an expandable slip ring, wherein the expandable slip ring is configured to expand by deforming radially outward; and one or more wedge rings configured to slide longitudinally upon application of sufficient longitudinal force and located with respect to the slip ring so that application of sufficient longitudinal force on the one or more wedge rings operates to drive the slip ring radially outward; wherein: the one or more wedge rings each comprise a wedge- like shape; the expandable plug seat has an unset configuration and a set configuration; in the unset configuration, the slip ring has an initial outer diameter that is less than the inner diameter of the casing; and in the set configuration, the outer diameter of the slip ring is configured to contact the inner diameter of the casing with sufficient force to hold the slip ring in place during subsequent operations.
  • the device of the first embodiment wherein the one or more wedge rings each comprise a vertex having an angle ranging from about 3-20 degrees (or alternatively 5-20, 10-20 or 5-10).
  • the device of the embodiments 1-2 wherein the expandable slip ring comprises an external elastomeric seal.
  • the device of embodiments 1-3 wherein the slip ring is configured to expand by plastic and/or elastic deformation radially outward into contact with the casing of the wellbore; and wherein, in the set configuration, the outer diameter of the slip ring contacts the inner diameter of the casing with sufficient force to form a seal therebetween.
  • the device of embodiments 1-4 wherein the slip ring comprises an outer surface, and the outer surface comprises a plurality of anchoring teeth for securely attaching the slip ring in place on the inner surface of the casing.
  • the device of embodiments 1-5 wherein the slip ring comprises an outer surface and a plurality of slots extending longitudinally and located radially around a circumference of the outer surface of the slip ring.
  • the device of embodiments 1-6 wherein the device consists essentially of only the slip ring and the one or more wedge rings.
  • the device of embodiments 1-7 wherein the one or more wedge rings and/or the slip ring are formed of dissolvable material.
  • the device of embodiments 1-8 further comprising a ball configured to seat on the one or more wedge rings and formed of dissolvable material.
  • the device of embodiments 1-9 wherein the device is configured to be made-up into a tool string with a wireline-conveyed power charge setting tool.
  • the device of embodiments 1-10 further comprising a mandrel and a lock ring, and wherein the mandrel comprises a ball seat and an angled outer surface portion located and oriented to work in conjunction with the wedge ring to drive the slip ring radially outward from the unset position to the set position when sufficient longitudinal force is applied to the wedge ring.
  • the device of embodiments 1-11 wherein the one or more wedge rings comprise two wedge rings; and wherein, in the unset configuration, one wedge ring is located below the slip ring and one wedge ring is located above the slip rings(or alternatively wherein the one or more wedge rings comprise only a single wedge ring which, in the unset configuration, is located above the slip ring).
  • a method of performing downhole operations within a cased wellbore using a plug seat wherein the plug seat includes a slip ring and one or more wedge rings located with respect to the slip ring so that application of sufficient longitudinal force on the one or more wedge rings operates to drive the slip ring radially outward, the method comprising the steps of: applying a sufficient longitudinal force onto the one or more wedge rings, thereby deforming the slip ring radially outward into contact with the casing.
  • the method of the thirteenth embodiment wherein the slip ring deforms plastically and/or elastically upon application of sufficient force via the one or more wedge rings, until the slip ring contacts the casing of the wellbore to securely affix the plug seat to the casing.
  • the method of embodiments 13-14 wherein the longitudinal force is applied to the one or more wedge rings by a wireline-conveyed power charge setting tool.
  • the method of embodiments 13-15 wherein the one or more wedge rings comprise an upper wedge ring located above the slip ring; the method further comprising landing a dissolvable ball on the upper wedge ring.
  • the method of embodiments 13-16 wherein the ball and/or wedge rings(s) and/or slip ring dissolves due to exposure to well conditions over time, thereby opening the wellbore without the need for drilling.
  • the method of embodiments 13-17 further comprising making-up a tool string comprising the plug seat, a wireline- conveyed power charge setting tool, and a perforating gun assembly.
  • the method of embodiments 13-18 further comprising positioning the plug seat in the wellbore, setting the plug seat using the wireline-conveyed power charge setting tool, and perforating the well casing, all in a single trip downhole.
  • the method of embodiments 13-19 wherein the wellbore comprises a horizontal portion, having a toe and a heel; the method further comprising repeatedly setting plug seat, perforating the wellbore, sealing the wellbore by landing ball on the plug seat, and fracturing the wellbore using a plurality of plug seats and balls proceeding from the toe of the horizontal portion of the wellbore towards the heel.
  • the method of embodiments 13-20 further comprising accessing the wellbore downstream of the plugseat (for ex. via tubing and/or wireline) without drilling the ball and/or wedge ring(s) and/or slip ring.
  • the method of embodiments 13-21 further comprising producing the well without drilling the ball and/or wedge ring(s) and/or slip ring.

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Abstract

L'invention concerne des modes de réalisation de procédés et dispositifs de mise en place d'un siège de bouchon au sein d'un puits de fond de trou, par exemple, dans des opérations de fracturation. Dans un mode de réalisation, le siège de bouchon expansible peut comprendre une bague collectrice expansible et une ou plusieurs bagues cunéiformes. Pour mettre en place le siège de bouchon expansible à l'intérieur du tubage du puits de forage, une force longitudinale serait typiquement appliquée à la ou aux bagues cunéiformes, ce qui permet de déformer la bague collectrice expansible et de l'entraîner radialement vers l'extérieur en contact avec le tubage dans le puits de forage. Dans certains modes de réalisation, le siège de bouchon expansible peut être utilisé avec une bille soluble, qui peut être pompée pour s'installer sur le siège de bouchon pour le scellage du puits de forage. Une fois que la section en aval du puits a été isolée de cette manière, des opérations de fracturation hydraulique peuvent commencer. Éventuellement, la bille peut se dissoudre, permettant d'accéder au puits de forage sans recourir à un perçage du bouchon.
PCT/US2015/057168 2014-10-23 2015-10-23 Siège de bouchon expansible WO2016065291A1 (fr)

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US62/067,594 2014-10-23

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