WO2014120543A1 - Ensemble siège de fond extensible - Google Patents

Ensemble siège de fond extensible Download PDF

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Publication number
WO2014120543A1
WO2014120543A1 PCT/US2014/012711 US2014012711W WO2014120543A1 WO 2014120543 A1 WO2014120543 A1 WO 2014120543A1 US 2014012711 W US2014012711 W US 2014012711W WO 2014120543 A1 WO2014120543 A1 WO 2014120543A1
Authority
WO
WIPO (PCT)
Prior art keywords
seat assembly
segments
seat
tubing string
well
Prior art date
Application number
PCT/US2014/012711
Other languages
English (en)
Inventor
Gregoire Jacob
Michael J. Bertoja
Original Assignee
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Holdings Limited
Schlumberger Technology B.V.
Prad Research And Development Limited
Schlumberger Technology Corporation
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
Priority claimed from US14/029,897 external-priority patent/US9752407B2/en
Application filed by Schlumberger Canada Limited, Services Petroliers Schlumberger, Schlumberger Holdings Limited, Schlumberger Technology B.V., Prad Research And Development Limited, Schlumberger Technology Corporation filed Critical Schlumberger Canada Limited
Priority to CA2899016A priority Critical patent/CA2899016A1/fr
Priority to AU2014212745A priority patent/AU2014212745B2/en
Publication of WO2014120543A1 publication Critical patent/WO2014120543A1/fr

Links

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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
    • 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
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E21B23/0411—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion specially adapted for anchoring tools or the like to the borehole wall or to well tube

Definitions

  • a variety of different operations may be performed when preparing a well for production of oil or gas. Some operations may be implemented to help increase the productivity of the well and may include the actuation of one or more downhole tools. Additionally, some operations may be repeated in multiple zones of a well. For example, well stimulation operations may be performed to increase the permeability of the well in one or more zones. In some cases, a sleeve may be shifted to provide a pathway for fluid communication between an interior of a tubing string and a formation. The pathway may be used to fracture the formation or to extract oil or gas from the formation. Another well stimulation operation may include actuating a perforating gun to perforate a casing and a formation to create a pathway for fluid communication. These and other operations may be performed using a various techniques, such as running a tool into the well on a conveyance mechanism to mechanically shift or inductively communicate with the tool to be actuated, pressurizing a control line, and so forth.
  • a technique includes deploying a seat assembly having a plurality of segments into a tubing string installed in a well and expanding the seat assembly at a downhole location in the well to secure the assembly to the tubing string and form a seat that is adapted to receive an untethered object.
  • the technique includes receiving the untethered object in the seat of the seat assembly.
  • the received untethered object in the seat assembly may be used to perform a downhole operation in the well.
  • an apparatus usable with a well includes a plurality of segments.
  • the apparatus is deployable in a tubing string installed in the well and the plurality of segments is adapted to expand to form a seat in the tubing string to receive an untethered object.
  • a system in yet another example implementation, includes a tubing string, an untethered object and a seat assembly. Segmented members of the seat assembly are adapted to be deployed into a tubing string, be radially expanded and be axially contracted to form a seat that is adapted to receive the untethered object.
  • Fig. 1 is a schematic diagram of a well according to an example implementation.
  • Fig. 2 illustrates a stimulation operation in a stage of the well of Fig. 1 according to an example implementation.
  • FIG. 3A is a schematic diagram of a well illustrating multiple stages with sleeves according to an example implementation.
  • Fig. 3B illustrates a seat assembly installed in a stage of the well of Fig. 3A according to an example implementation.
  • Fig. 3C illustrates an untethered object landing on the seat assembly of Fig. 3B according to an example implementation.
  • Fig. 3D illustrates a sleeve in a stage of the well shifted by the untethered object of Fig. 3C according to an example implementation.
  • Fig. 3E illustrates the shifted sleeve of Fig. 3D with the untethered object dissolved according to an example implementation.
  • Fig. 4 is a schematic view illustrating an expandable, segmented seat assembly in a contracted state and inside a tubing string according to an example implementation.
  • Fig. 5 is a cross-sectional view taken along line 5-5 of Fig. 4 according to an example implementation.
  • Fig. 6 is a cross-sectional view taken along line 6-6 of Fig. 4 according to an example implementation.
  • Fig. 7 is a perspective view of the seat assembly in an expanded state according to an example implementation.
  • Fig. 8 is a top view of the seat assembly of Fig. 7 according to an example implementation.
  • Fig. 9 is a flow diagram depicting a technique to deploy and use an expandable seat assembly according to an example implementation.
  • Fig. 10 is a cross-sectional view of the seat assembly in an expanded state inside a tubing string according to an example implementation.
  • Fig. 11 is a cross-sectional view of the seat assembly in an expanded state inside a tubing string and in receipt of an activation ball according to an example implementation.
  • FIGs. 12 and 13 are perspective views of expandable seat assemblies according to further example implementations.
  • Fig. 14 is a cross-sectional view of the seat assembly taken along line 14- 14 of Fig. 13 when the seat assembly is in receipt of an activation ball according to an example implementation.
  • Fig. 15 is a flow diagram depicting a technique to deploy and use an expandable seat assembly according to a further example implementation.
  • Fig. 16A is a perspective view of a seat assembly setting tool and a segmented seat assembly according to an example implementation.
  • Fig. 16B is a bottom view of the seat assembly setting tool and seat assembly of Fig. 16A according to an example implementation.
  • Fig. 16C is a cross-sectional view taken along line 16C-16C of Fig. 16A according to an example implementation.
  • Fig. 17 is a cross-sectional view of a seat assembly setting tool and a segmented seat assembly according to a further example implementation.
  • Figs. 18A, 18B, 18C, 18D, 18E and 18F are cross-sectional views illustrating use of the setting tool to expand an upper segment of the seat assembly to transition the seat assembly to an expanded state according to an example
  • Figs. 19A, 19B, 19C, 19D, 19E and 19F are cross-sectional views illustrating use of the setting tool to expand a lower segment of the seat assembly to transition the seat assembly to the expanded state according to an example
  • FIGs. 20A, 20B, 20C and 20D are cross-sectional views illustrating use of a setting tool to expand an upper segment of the seat assembly to transition the seat assembly to the expanded state according to a further example implementation.
  • Figs. 21A, 21B, 21C and 21D are cross-sectional views illustrating use of a setting tool to expand a lower segment of the seat assembly to transition the seat assembly to the expanded state according to a further example implementation.
  • Figs. 22A, 22B, 22C, 22D, 22E and 22F are cross-sectional views of a setting tool and a segmented seat assembly illustrating use of the setting tool to expand an upper segment of the seat assembly to transition the seat assembly to the expanded state according to an example implementation.
  • Fig. 22G is a cross-sectional view taken along line 22G-22G of Fig. 22A according to an example implementation.
  • Figs. 22H, 221, 22J and 22K are cross-sectional views of the setting tool and the segmented seat assembly illustrating use of the setting tool to expand a lower segment of the seat assembly to transition the seat assembly to the expanded state according to an example implementation.
  • Fig. 23 is a flow diagram depicting a technique to use a setting tool to transition a segmented seat assembly between contracted and expanded states according to example implementations.
  • Figs. 24A and 24B illustrate surfaces of the rod and mandrel of a seat assembly setting tool for a two layer seat assembly according to an example
  • Figs. 25A, 25B and 25C illustrate surfaces of the rod and mandrel of a seat assembly setting tool for a three layer seat assembly according to an example
  • FIGS. 26A, 26B, 26C and 26D illustrate surfaces of the rod and mandrel of a seat assembly setting tool for a four layer seat assembly according to an example implementation.
  • Fig. 27 is a perspective view of a seat assembly according to an example implementation.
  • the systems and techniques may be used in a well for purposes of performing a downhole operation.
  • the seat assembly that is disclosed herein may be run downhole in the well in a passageway of a tubing string that was previously installed in the well and secured to the tubing string at a desired location in which a downhole operation is to be performed.
  • the tubing string may take the form of multiple pipes coupled together and lowered into a well.
  • the downhole operation may be any of a number of operations (stimulation operations, perforating operations, and so forth) that rely on an object being landed in a seat of the seat assembly.
  • the seat assembly is an expandable, segmented assembly, which has two states: an unexpanded state and an expanded state.
  • the unexpanded state has a smaller cross-section than the expanded state.
  • the smaller cross-section allows running of the seat assembly downhole inside a tubing string.
  • the expanded state forms a seat (e.g., a ring) that is constructed to catch an object deployed in the string.
  • the seat and the object together may form a downhole fluid obstruction, or barrier.
  • the seat assembly in its expanded state, is constructed to receive, or catch, an untethered object deployed in the tubing string.
  • the "untethered object” refers to an object that is communicated downhole through the tubing string without the use of a conveyance line (a slickline, a wireline, a coiled tubing string and so forth) for at least a portion of its travel through the tubing string.
  • a conveyance line a slickline, a wireline, a coiled tubing string and so forth
  • the untethered object may take the form of a ball (or sphere), a dart or a bar.
  • the untethered object may, in accordance with example implementations, be deployed on the end of a tool string, which is conveyed into the well by wireline, slickline, coiled tubing, and so forth. Moreover, the untethered object may be, in accordance with example implementations, deployed on the end of a tool string, which includes a setting tool that deploys the segmented seat assembly.
  • the seat assembly is a segmented apparatus that contains multiple curved sections that are constructed to radially contract and axially expand into multiple layers to form the contracted state.
  • the sections are constructed to radially expand and axially contract into a single layer to form a seat in the expanded state of the seat assembly to catch an object.
  • a setting tool may be used to contact the sections of the seat assembly for purposes of transitioning the seat assembly between the expanded and contracted states, as further described herein.
  • a well 10 includes a wellbore 15.
  • the wellbore 15 may traverse one or more hydrocarbon-bearing formations.
  • a tubing string 20, as depicted in Fig. 1 can be positioned in the wellbore 15.
  • the tubing string 20 may be cemented to the wellbore 15 (such wellbores are typically referred to as "cased hole” wellbores); or the tubing string 20 may be secured to the surrounding formation(s) by packers (such wellbores typically are referred to as "open hole” wellbores).
  • the wellbore 15 may extend through multiple zones, or stages 30 (four example stages 30a, 30b, 30c and 30d, being depicted in Fig. 1, as examples), of the well 10.
  • Fig. 1 and other figures disclosed herein depict a lateral wellbore
  • the techniques and systems that are disclosed herein may likewise be applied to vertical wellbores.
  • the well 10 may contain multiple wellbores, which contain tubing strings that are similar to the illustrated tubing string 20 of Fig. 1.
  • the well 10 may be a subsea well or may be a terrestrial well, depending on the particular implementations.
  • the well 10 may be an injection well or may be a production well.
  • many implementations are contemplated, which are within the scope of the appended claims.
  • Downhole operations may be performed in the stages 30 in a particular directional order, in accordance with example implementations.
  • downhole operations may be conducted in a direction from a toe end of the wellbore to a heel end of the wellbore 15, in accordance with some implementations.
  • these downhole operations may be connected from the heel end to the toe end (e.g., terminal end) of the wellbore 15.
  • the operations may be performed in no particular order, or sequence.
  • Fig. 1 depicts that fluid communication with the surrounding hydrocarbon formation(s) has been enhanced through sets 40 of perforation tunnels that, for this example, are formed in each stage 30 and extend through the tubing string 20. It is noted that each stage 30 may have multiple sets of such perforation tunnels 40. Although perforation tunnels 40 are depicted in Fig. 1, it is understood that other techniques may be used to establish/enhance fluid communication with the surrounding formation (s), as the fluid communication may be established using, for example, a jetting tool that communicates an abrasive slurry to perforate the tubing string wall; opening sleeve valves of the tubing string 20; and so forth.
  • a stimulation operation may be performed in the stage 30a by deploying an expandable, segmented seat assembly 50 (herein called the "seat assembly") into the tubing string 20 on a setting tool (as further disclosed herein) in a contracted state of the assembly 50.
  • the assembly 50 In the contracted state, the assembly 50 has an outer diameter to allow it to be run-in-hole.
  • the seat assembly 50 is expanded downhole in the well. In its expanded state, the seat assembly 50 has a larger outer diameter than in its contracted state. Additionally, the seat assembly 50 is shorter longitudinally in the expanded stated than the contracted state.
  • the seat assembly 50 engages, and is secured on, an inner surface of the tubing string 20 at a targeted location in the stage 30a.
  • the seat assembly 50 is secured in the tubing string 20 near the bottom, or downhole end, of the stage 30a.
  • an untethered object here, an activation ball 150
  • the fluid barrier may be used to direct fracture fluid (e.g., fracture fluid pumped into the tubing string 20 from the Earth surface) into the stage 30a.
  • FIG. 3A depicts an example tubing string 312 of a well 300, which has a central passageway 314 and extends through associated stages 30a, 30b, 30c and 30d of the well 300.
  • Each stage 30 has an associated sleeve 240, which resides in a recess 231 of the tubing string 312.
  • the sleeve 240 may have been previously positioned in the stage 30.
  • the sleeve 240 is positioned in the well in a closed state and therefore covers radial ports 230 in the tubing string wall.
  • each stage 30 may be associated with a given set of radial ports 230, so that by communicating an untethered object downhole inside the passageway 314 of the tubing string 312 and landing the ball in a seat of a seat assembly 237 (see Fig. 3B), a corresponding fluid barrier may be formed to divert fluid through the associate set of radial ports 230.
  • FIG. 3B As shown, the seat assembly 237 has been deployed (attached, anchored, swaged) to the sleeve 240.
  • a shoulder 238 on the sleeve 240 which engages a corresponding shoulder of the seat assembly 237 may be provided to connect the seat assembly 237 and the sleeve 240.
  • Other connection methods may be used, such as recess on the sleeve 240, a direct anchoring with the seat assembly 237, and so forth.
  • the seat assemblies 237 may be installed one by one after the stimulation of each stage 30 (as discussed further below); or multiple seat assemblies 237 may be installed in a single trip into the well 300. Therefore, the seat, or inner catching diameter of the seat assembly 237, for the different assemblies 237, may have different dimensions, such as inner dimensions that are relatively smaller downhole and progressively become larger moving in an uphole direction (e.g., towards surface). This can permit the use of differently- sized untethered objects to land on the seat assemblies 237 without further downhole intervention. Thus, continuous pumping treatment of multiple stages 30 may be achieved.
  • FIG. 3C this figure depicts the landing of the untethered object 150 on the seat assembly 237 of the stage 30a. At this point, the untethered object 150 has been caught by the seat assembly 237.
  • Fig. 3D due to the force that is exerted by the untethered object 150, due to, for example, either the momentum of the untethered object 150 or the pressure differential created by the untethered object, the sleeve 240 and the seat assembly 237 can be shifted downhole, revealing the radial ports 230. In this position, a pumping treatment (the pumping of a fracturing fluid, for example) may be performed in the stage 30a.
  • a pumping treatment the pumping of a fracturing fluid, for example
  • Fig. 3E depicts the stage 30a with the sleeve 240 in the opened position and with the seat assembly 237 and untethered object 150 being dissolved, as further discussed below.
  • Fig. 4 is a perspective of the seat assembly 50, and Figs. 5 and 6 illustrate cross-sectional views of the seat assembly 50 of Fig. 4, in accordance with an example implementation.
  • this figure depicts the seat assembly 50 in a contracted state, i.e., in a radially collapsed state having a smaller outer diameter, which facilitates travel of the seat assembly 50 downhole to its final position.
  • the seat assembly, 50 for this example implementation, has two sets of arcuate segments: three upper segments 410; and three lower segments 420. In the contracted state, the segments 410 and 420 are radially contracted and are longitudinally, or axially, expanded into two layers 412 and 430.
  • the upper segment 410 can have a curved wedge that has a radius of curvature about the longitudinal axis of the seat assembly 50 and can be larger at its top end than at its bottom end.
  • the lower segment 420 can have an arcuate wedge that has a radius of curvature about the longitudinal axis (as the upper segment 410) and can be larger at its bottom end than at its top end.
  • the two layers 412 and 430 longitudinally, or axially, compress into a single layer of segments such that each upper segment 410 is complimentarily received between two lower segments 420, and vice versa, as depicted in Fig. 7.
  • the seat assembly 50 forms a tubular member having a seat that is sized to catch an untethered object deployed in the tubing string 20.
  • each of the segments 410 and 420 can form a corresponding section of a seat ring 730 (i.e., the "seat") of the seat assembly 50 when the assembly 50 is in its expanded state.
  • a seat ring 730 i.e., the "seat"
  • the seat ring 730 of the seat assembly 50 defines an opening 710 sized to control the size of objects that pass through the seat ring 730 and the size of objects the seat ring 730 catches.
  • a technique 900 includes deploying (block 902) a segmented seat assembly into a tubing string and radially expanding (block 904) the seat assembly to attach the seat assembly to a tubing string at a downhole location and form a seat to receive an untethered object.
  • a seat of the seat assembly catches an object and is used to perform a downhole operation (block 908).
  • the seat assembly 50 may attach to the tubing string in numerous different ways, depending on the particular implementation.
  • Fig. 10 depicts an example tubing string 20 that contains a narrowed seat profile 1020, which complements an outer profile of the seat assembly 50 in its expanded state.
  • the segments 410 and 420 contain corresponding outer profiles 1010 that engage the tubing profile 1010 to catch the seat assembly 50 on the profile 1020.
  • the tubing string 50 has a sufficiently small cross-section, or diameter for purposes of forming frictional contact to allow a setting tool to transition the seat assembly 50 to the expanded state, as further disclosed herein.
  • the full radial expansion and actual contraction of the seat assembly 50 may be enhanced by the reception of the untethered object 150.
  • the untethered object 150 has a diameter that is sized to land in the seat ring 730 and further expands the seat assembly 50.
  • Fig. 12 depicts a seat assembly 1200 that has similar elements to the seat assembly 50, with similar reference numerals being used to depict similar elements.
  • the seat assembly 1200 has segments 1220 that replace the segments 420.
  • the segments 1220 can be arcuate and wedge-shaped sections similar to the segments 420.
  • the segments 1220 have anchors, or slips 1230, that are disposed on the outer surface of the segments 1220 for purposes of securing or anchoring the seat assembly 1200 to the tubing string wall when the segments 1220 radially expand.
  • Fig. 13 depicts a seat assembly 1300 that that has similar elements to the seat assembly 1200, with similar reference numerals being used to depict similar elements.
  • the seat assembly 1300 can contain fluid seals.
  • the seat assembly 1300 has fluid seals 1320 that are disposed between the axially extending edges of the segments 410 and 1220.
  • the fluid seals 1320 help to create a fluid seal when an object lands on the seat assembly 1300.
  • the seat assembly 1300 includes a peripherally extending seal element 1350 (an o-ring, for example), which extends about the periphery of the segments 410 and 1220 to form a fluid seal between the outer surface of the expanded seat assembly 1300 and the inner surface of the tubing string wall.
  • Fig. 14 depicts a cross-sectional view of the seat assembly 1300 of Fig. 13 in the radially expanded state when receiving an untethered object 150.
  • the collective outer profile of the segments 410 and 420 may be contoured in a manner to form an object that engages a seat assembly that is disposed further downhole.
  • the seat assembly may then be transitioned (via a downhole tool, for example) into its radially contracted state so that the seat assembly (or a portion thereof) may travel further downhole and serve as an untethered object to perform another downhole operation.
  • a segmented seat assembly 2700 of Fig. 27 may be used having upper seat segments 410 and lower seat segments 420 similar to the seat segments discussed above.
  • the segmented seat assembly 2700 includes a lower contoured cap 2710, which is profiled.
  • the lower contoured cap 2710 may include beveled features, as depicted at reference number 2714.
  • the lower contoured cap 2710 may form a contoured profile to engage a seat that is positioned below the segmented seat assembly 2700 after the segmented seat assembly 2700 is released.
  • the cap 2710 may be attached to the lower seat segments 420.
  • a technique 1500 includes releasing (block 1502) a first seat assembly from being attached to a tubing string and receiving (block 1504) a bottom profile of the first seat assembly in a second seat assembly. Pursuant to the technique 1500, the received first seat assembly may then be used to perform a downhole operation (block 1506).
  • a setting tool 1600 may be used to transition the seat assembly 50 between its contracted and expanded states.
  • the setting tool 1600 includes components that move relative to each other to expand or contract the seat assembly 50: a rod 1602 and a mandrel 1620 which generally circumscribes the rod 1602.
  • the relative motion between the rod 1602 and the mandrel 1620 causes surfaces of the mandrel 1620 and rod 1602 to contact the upper 410 and lower 420 segments of the seat assembly 50 to radially expand the segments 410 and 420 and longitudinally contract the segments into a single layer to form the seat, as described above.
  • the rod 1602 and mandrel 1620 may be generally concentric with a longitudinal axis 1601 and extend along the longitudinal axis 1601.
  • An upper end 1612 of the rod 1602 may be attached to a conveyance line (a coiled tubing string, for example).
  • a bottom end 1610 of the rod 1602 may be free or attached to a downhole tool or string, depending on the particular implementation.
  • the rod 1602 contains radially extending vanes 1608 for purposes of contacting inner surfaces of the seat assembly segments 410 and 420: vanes 1608-1 to contact the upper segments 410; and vanes 1608-2 to contact the lower segments 420.
  • the setting tool 1600 includes six vanes 1608, i.e., three vanes 1608-1 contacting for the upper segments 410 and three vanes 1608-2 for contacting the lower segments 420.
  • the vanes 1608 may be equally distributed around the longitudinal axis 1601 of the setting tool 1600, in accordance with example implementations.
  • Fig. 17 depicts a cross-sectional view for the seat assembly setting tool 1600 according to a further implementation.
  • the setting tool 1600 includes a bottom compression member 1710 that is disposed at the lower end of the rod 1602.
  • the compression member 1710 aids in exerting a radial setting force on the segments 410 and 420 and may be released from the setting tool 1600 and left downhole with the expanded seat assembly (after the remainder of the setting tool 1600 is retrieved from the well) to form a retaining device for the seat assembly, as further discussed below.
  • Fig. 18A depicts a partial cross-sectional view of the setting tool 1600, according to an example implementation, for purposes of illustrating forces that the tool 1600 exerts on the lower segment 410. It is noted that Fig. 18a depicts one half of the cross-section of the setting tool 1600 about the tool's longitudinal axis 1601, as can be appreciated by the skilled artisan.
  • an inclined, or sloped, surface 1820 of the vane 1608-1 and a sloped surface 1824 of the mandrel 1620 act on the upper segment 410 as illustrated in Fig. 18 A.
  • the sloped surface 1820 of the vane 1608-1 forms an angle l (with respect to the longitudinal axis 1601), which contacts an opposing sloped surface 1810 of the segment 410.
  • the sloped surface 1824 of the mandrel 1620 is inclined at an angle ⁇ with respect to the longitudinal axis 1601. The sloped surface 1824 of the mandrel 1820, in turn, contacts an opposing sloped surface 1812 of the upper segment 410.
  • the surfaces 1820 and 1824 have respective surface normals, which, in general, are pointed in opposite directions along the longitudinal axis 1601. Therefore, by relative movement of the rod 1602 in the illustrated uphole direction 1830, the surfaces 1820 and 1824 of the setting tool 1600 produce a net outward radial force 1834 on the segment 410, which tends to radially expand the upper segment 410. Moreover, the relative movement of the rod 1602 and mandrel 1620 produces a force 1832 that causes the segment 410 to longitudinally translate to a position to compress the segments 410 and 420 into a single layer.
  • the vane 1608-2 of the rod 1602 has a sloped surface 1920, which contacts a corresponding sloped surface 1910 of the lower segment 420; and the mandrel 1620 has a sloped surface 1914 that contacts a corresponding opposing sloped surface 1912 of the lower segment 420.
  • the slope surfaces 1914 and 1920 having opposing surface normals, which cause the relative movement between the rod 1602 and mandrel 1620 to produce a net radially outward force 1934 on the lower segment 410.
  • the l and a2 angles may be the same; and the ⁇ and ⁇ 2 angles may be same.
  • different angles may be chosen (i.e., the al and o2 angles may be different, as well as the ⁇ and ⁇ 2 angles, for example), depending on the particular implementation.
  • Having different slope angles involves adjusting the thicknesses and lengths of the segments of the seat assembly 50, depending on the purpose to be achieved. For example, by adjusting the different slope angles, the seat assembly 50 and corresponding setting tool may be designed so that the segments of the seat assembly are at the same height when the seat assembly 50 is fully expanded or a specific offset.
  • the choice of the angles may be used to select whether the segments of the seat assembly finish in an external circular shape or with specific radial offsets.
  • the relationship of the a angles (i.e., the al and a2 angles) relative to the ⁇ angles (i.e., the ⁇ and ⁇ 2 angles) may be varied, depending on the particular implementation.
  • the a angles may be less than the ⁇ angles.
  • the ⁇ angles may be in a range from one and one half times the a angle to ten times the a angle, but any ratio between the angles may be selected, depending on the particular implementation.
  • choices involving different angular relationships may depend on such factors as the axial displacement of the rod 1602, decisions regarding adapting the radial and/or axial displacement of the different layers of the elements of the seat assembly 50; adapting friction forces present in the setting tool and/or seat assembly 50; and so forth.
  • Fig. 18B depicts further movement (relative to Fig. 18 A) of the rod 1602 with respect to the upper segment 410 mandrel 1620, resulting in full radial expansion of the upper seat segment 410; and Fig. 18B also depicts stop shoulders 1621 and 1660 that may be used on the mandrel 1620 and rod 1602, in accordance with some example implementations. In this manner, for the state of the setting that is depicted in Fig.
  • Fig. 19B illustrates full radial expansion of the lower seat segment 420, which occurs when relative travel between the rod 1602 and the mandrel 1620 is halted due to the segment 420 resting between a stop shoulder 1625 of the mandrel 1620 and a stop shoulder 1662 of the vane 1608-2.
  • the tool 1600 includes a bottom compression member that is attached to the lower end of the mandrel 1620 and has corresponding member parts 1850 (contacting the segments 410) and 1950 (contacting the segments 420).
  • compression members 1850 and 1950 may be the same part but are depicted in the figures at two different cross-sections for clarity.
  • the vane 1608- 1 contains a compression member part 1850; and the vane 1608-2 depicted in Figs. 19A and 19B depicts a compression member part 1950.
  • the mandrel of a setting tool may not include such an extension.
  • the rod of the setting tool moves with respect to the mandrel
  • the mandrel may move with respect to the rod.
  • the bottom compression member of the rod 1602 may be attached to the remaining portion of the rod using one or more shear devices.
  • Fig. 18C depicts the compression member part 1850 being attached to the rest of the vane 1608-1 using a shear device 1670, such as a shear screw, for example.
  • Fig. 19C depicts the compression member part 1950 being attached to the remainder of the vane 1608-2 using a corresponding shear device 1690.
  • the use of the compression member, along with the shear device(s) allows the setting tool to leave the compression member downhole to, in conjunction with the seat assembly 50, form a permanently-set seat in the well.
  • the force that is available from the setting tool 1600 actuating the rod longitudinally and the force-dependent linkage that is provided by the shear device provide a precise level of force transmitted to the compression member.
  • This force is transmitted to the segments of the seat assembly 50 before the compression member separates from the rod 1602.
  • the compression member therefore becomes part of the seat assembly 50 and is released at the end of the setting process to expand the seat assembly 40.
  • the compression piece may be attached to the segments or may be a separate piece secured by one or more shear devices.
  • additional force i.e., additional longitudinal forces 1674 (Fig. 18C) and 1680 (Fig. 19C); or additional radial forces 1676 (Fig. 18C) or 1684 (Fig. 19C); or a combination of both, may be applied to the seat assembly 50 to aid in expanding the seat assembly.
  • the above-described forces may be transmitted to a self-locking feature and/or to an anti-return feature.
  • These features may be located, for example, on the side faces of the seat assembly's segments and/or between a portion of the segments and the compression piece.
  • self-locking features may be formed from tongue and groove connections, which use longitudinally shallow angles (angles between three and ten degrees, for example) to obtain a self-locking imbrication between the parts due to contact friction.
  • Anti-return features may be imparted, in accordance with example implementations, using, for example, a ratchet system, which may be added on the external faces of a tongue and groove configuration between the opposing pieces.
  • the ratchet system may, in accordance with example implementations, contain spring blades in front of anchoring teeth.
  • the anti-return features may also be incorporated between the segment (such as segment 410) and the compression member, such as compression member 1850.
  • Figs. 18D, 19D, 18E, 19E, 18F and 19F depict using of the bottom compression member along with the shear devices, in accordance with an example implementation.
  • FIGs. 18D and 19D depict separation of the compression member parts 1850 (Fig. 18D) and 1950 (Fig. 18E) from the rod 1602, thereby releasing the compression member from the rest of the setting tool, as illustrated in Figs. 18E and 19E.
  • Figs. 18F and 19F after removal of the remainder of the setting tool 1600, the segments 410 (Fig. 18F) and 420 (Fig. 19F) and
  • the segments 410 and/or 420 of the seat assembly may contain anchors, or slips, for purposes of engaging, for example, a tubing string wall to anchor, or secure the seat assembly to the string.
  • the setting tool may contain a lower compression member on the rod, which serves to further expand radially the formed ring and further allow the ring to be transitioned from its expanded state back to its contracted state.
  • a lower compression member on the rod which serves to further expand radially the formed ring and further allow the ring to be transitioned from its expanded state back to its contracted state.
  • Figs. 20A, 20B, 20C and 20D depict the actions of setting tool 2000 against the upper seat segment 410; and Figs. 21A, 21B, 21C and 21D depict the actions of the setting tool 2000 against the lower seat segment 420.
  • the setting tool 2000 does not have a lower compression member, thereby allowing the rod 1602 to be moved in a longitudinal direction (as illustrated by directions 210 of Fig. 20B and 2014 of Fig. 2 IB) to radially expand the segments 410 and 420 and leave the segments 410 and 420 in the well, as illustrated in Figs. 20D and 21D.
  • Fig. 22A depicts a seat assembly setting tool 2200 according to further implementations.
  • a mandrel 2201 of the tool 2200 includes the above-described inclined faces to contact seat assembly segments.
  • the mandrel 2201 also contains an end sloped segment on its outer diameter to ease the radial expansion of the segments while having a small axial movement for purposes of reducing friction and providing easier sliding movement.
  • the mandrel 2201 contains a portion 2250 that has an associated sloped surface 2252 that engages a corresponding sloped surface 2213 of the upper seat segment 410.
  • the sloped surface 2252 forms an associated angle (called " ⁇ ") with respect to the radial direction from the longitudinal axis 1601.
  • the portion 2250 may have a sloped surface 2253 (see Fig. 22F) that engages a corresponding sloped surface 2215 of the lower seat segment 420 and forms an angle (called " ⁇ 2 ⁇ ) with respect to the radial direction.
  • the angles ⁇ 1 and ⁇ 2 may be, equal to or steeper than the steepest of the a angles (the l and a2 angles) and the ⁇ angles (the ⁇ and ⁇ 2 angles), in accordance with some implementations.
  • an additional sloped surface may be added, in accordance with example implementations, in a different radial orientation than the existing sloped surface with the angle l for the upper segment 410 and ⁇ for the lower segment 420.
  • the tool 2200 includes a lower compression piece 2204 that includes a sloped surface 2220 having an angle ⁇ with respect to the longitudinal axis 1601.
  • the angle ⁇ may be relatively shallow (a three to ten degree angle, for example, with respect to the longitudinal axis 1601) to obtain a self- locking contact between the upper seat segment 410 and the compression piece 2204.
  • a three to ten degree angle for example, with respect to the longitudinal axis 1601
  • the upper seat segment 410 has sloped surfaces 2220 with the ⁇ angle and a sloped surface 2280 with the al angle.
  • the lower seat segment 420 may have surfaces that are inclined at angles a2 and ⁇ 2 .
  • the ⁇ 2 angle may be relatively shallow, similar to the ⁇ angle for purposes of obtaining a self-locking contact between the lower seat segment 420 and the compression piece.
  • the lower seat segment 420 is attached to, or integral with teeth, or slips 2292 (see Fig. 22H, for example), which engage the inner surface of the tubing string 20.
  • the upper seat segment 410 may be attached to/integral with such slips, in accordance with further implementations and/or the seat segments 410 and 420 may be connected to slips; and so forth.
  • the setting tool 2200 may operate as follows. As shown in Fig. 22B, upon movement of the rod 1602 along a direction 2280, the upper seat segment 410 radially expands due to a resultant force along a radial direction 2260. At this point, the rod 1602 and compression piece 2204 remain attached. Referring to Fig. 22H, the lower seat segment 420 radially expands as well, which causes the slips 2292 to engage the tubing string wall. Upon further movement of the rod 1602 in the direction 2280, the compression piece 2204 separates from the remaining portion of the rod 1602, as illustrated in Fig. 22C. In a similar manner, referring to Fig. 221, this separation also occurs in connection with the components engaging the lower seat segment 420.
  • the segments are anchored, or otherwise attached, to the tubing string wall, so that, as depicted in Figs. 22D and 22J, the remaining rod and mandrel may be further retracted uphole, thereby leaving the compression piece and segment down in the well, as further illustrated in Figs. 22E and 22K.
  • the segmented seat assembly may be deployed inside an expandable tube so that radial expansion of the segmented seat assembly deforms the tube to secure the seat assembly in place.
  • the segmented seat assembly may be deployed in an open hole and thus, may form an anchored connection to an uncased wellbore wall.
  • the slip elements may be secured to the lower seat segments, such as lower seat segments 420, so that the upper seat segments 410 may rest on the lower seat segments 420 after the untethered object has landed in the seat of the seat assembly.
  • the rod may be moved back downhole to exert radial retraction and longitudinal expansion forces to return the seat assembly back into its contracted state.
  • a technique 2300 that is depicted in Fig. 23 may be performed in a well using a setting tool and a segmented seat assembly.
  • a tool and seat assembly is positioned in a recess of a tubing string (as an example) and movement of the tool is initiated, pursuant to block 2304.
  • the technique 2300 includes transitioning the seat assembly to an expanded state, releasing the assembly from the tool, performing a downhole operation and then reengaging the seat assembly with the setting tool to transition the seat assembly back to the contracted state. If more downhole locations are to be performed (decision block 2314), then control transitions back to box 2304.
  • the technique 2300 includes transitioning the seat assembly to the expanded state and releasing the assembly from the tool, pursuant to block 2308. If the setting tool contains the compression piece but multiple expansions and retractions of the seat assembly is not to be used (decision block 2310), then use of the tool depends on whether anchoring (decision block 2320) is to be employed. In other words, if the seat assembly is to be permanently anchored, then the flow diagram 2300 includes transitioning the seat assembly to the expanded state to anchor the setting tool to the tubing string wall and releasing the assembly from the tool, thereby leaving the compression piece downhole with the seat assembly to form a permanent seat in the well.
  • the technique 2300 includes transitioning the seat assembly to the expanded state and releasing the seat assembly from the tool, pursuant to block 2326, without separating the compression piece from the rod of the setting tool, pursuant to block 2326.
  • Fig. 24A and 24B depict surfaces 2410 and 2414 (Fig. 24A) for an upper segment of a two layer seat assembly and corresponding surfaces 2420 and 2424 (Fig. 24B) for the lower segment of the two layer assembly.
  • Figs. 25A, 25B and 25C depict surfaces 2510 and 2514 (Fig. 25A), 2520 and 2524 (Fig.
  • Figs. 25B), and 2530 and 2534 depict surfaces of the rod and mandrel for upper-to-lower segments of a four layer segmented seat assembly.

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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 une technique, qui comprend le déploiement d'un ensemble siège ayant une pluralité de segments dans un tube de production monté dans un puits, et l'extension de l'ensemble siège à un emplacement de fond dans le puits pour fixer l'ensemble au tube de production et former un siège qui est conçu pour recevoir un objet non attaché. La technique comprend la réception de l'objet non attaché dans le siège de l'ensemble siège et l'utilisation de l'objet non attaché reçu dans l'ensemble siège pour exécuter une opération de fond dans le puits.
PCT/US2014/012711 2013-02-01 2014-01-23 Ensemble siège de fond extensible WO2014120543A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
CA2899016A CA2899016A1 (fr) 2013-02-01 2014-01-23 Ensemble siege de fond extensible
AU2014212745A AU2014212745B2 (en) 2013-02-01 2014-01-23 Expandable downhole seat assembly

Applications Claiming Priority (10)

Application Number Priority Date Filing Date Title
US201361759599P 2013-02-01 2013-02-01
US201361759577P 2013-02-01 2013-02-01
US201361759592P 2013-02-01 2013-02-01
US201361759584P 2013-02-01 2013-02-01
US61/759,599 2013-02-01
US61/759,592 2013-02-01
US61/759,584 2013-02-01
US61/759,577 2013-02-01
US14/029,897 2013-09-18
US14/029,897 US9752407B2 (en) 2011-09-13 2013-09-18 Expandable downhole seat assembly

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WO2014120543A1 true WO2014120543A1 (fr) 2014-08-07

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GB2549925A (en) * 2016-03-15 2017-11-08 Weatherford Uk Ltd Downhole slip apparatus
EP3674515A1 (fr) * 2016-05-06 2020-07-01 Stephen L. Crow Procédé d'isolation de puits avec outil de pose pour un support de siège adaptatif monté sur un évidement pour un objet utilisé pour le traitement séquentiel de sections de zone avec et sans fraisage

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CN106223920B (zh) * 2016-08-19 2018-07-27 重庆市能源投资集团科技有限责任公司 一种多煤层滑套隔离分层压裂装置及方法

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US20060131031A1 (en) * 2004-12-21 2006-06-22 Mckeachnie W J Wellbore tool with disintegratable components
US7114559B2 (en) * 2002-02-11 2006-10-03 Baker Hughes Incorporated Method of repair of collapsed or damaged tubulars downhole
US7628210B2 (en) * 2007-08-13 2009-12-08 Baker Hughes Incorporated Ball seat having ball support member
US7673677B2 (en) * 2007-08-13 2010-03-09 Baker Hughes Incorporated Reusable ball seat having ball support member
US20120261115A1 (en) * 2011-04-13 2012-10-18 Ying Qing Xu Ball seat having ball support member

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FR2894317B1 (fr) * 2005-12-07 2008-02-29 Geoservices Mandrin destine a etre dans un conduit de circulation d'un fluide et puits d'exploitation de fluide associe.
US9303475B2 (en) * 2010-06-29 2016-04-05 Baker Hughes Incorporated Tool with multisize segmented ring seat

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US7114559B2 (en) * 2002-02-11 2006-10-03 Baker Hughes Incorporated Method of repair of collapsed or damaged tubulars downhole
US20060131031A1 (en) * 2004-12-21 2006-06-22 Mckeachnie W J Wellbore tool with disintegratable components
US7628210B2 (en) * 2007-08-13 2009-12-08 Baker Hughes Incorporated Ball seat having ball support member
US7673677B2 (en) * 2007-08-13 2010-03-09 Baker Hughes Incorporated Reusable ball seat having ball support member
US20120261115A1 (en) * 2011-04-13 2012-10-18 Ying Qing Xu Ball seat having ball support member

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2549925A (en) * 2016-03-15 2017-11-08 Weatherford Uk Ltd Downhole slip apparatus
US10480262B2 (en) 2016-03-15 2019-11-19 Weatherford U.K. Limited Downhole slip apparatus
EP3674515A1 (fr) * 2016-05-06 2020-07-01 Stephen L. Crow Procédé d'isolation de puits avec outil de pose pour un support de siège adaptatif monté sur un évidement pour un objet utilisé pour le traitement séquentiel de sections de zone avec et sans fraisage

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CA2899016A1 (fr) 2014-08-07
AU2014212745A1 (en) 2015-08-06

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