EP3094813B1 - Sealing element for downhole tool - Google Patents
Sealing element for downhole tool Download PDFInfo
- Publication number
- EP3094813B1 EP3094813B1 EP14888977.7A EP14888977A EP3094813B1 EP 3094813 B1 EP3094813 B1 EP 3094813B1 EP 14888977 A EP14888977 A EP 14888977A EP 3094813 B1 EP3094813 B1 EP 3094813B1
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- EP
- European Patent Office
- Prior art keywords
- sealing member
- sealing
- wall
- wedge
- downhole tool
- Prior art date
- Legal status (The legal status 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 status listed.)
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 the boreholes or wells
- E21B23/01—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for anchoring the tools or the like
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 the boreholes or wells
- E21B23/06—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for setting packers
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B33/1293—Packers; Plugs with mechanical slips for hooking into the casing with means for anchoring against downward and upward movement
Definitions
- This invention relates to tools used in oil and gas wellbores. More specifically, the disclosure relates to expansion sealing elements used to prevent fluid flow through an annulus formed by a tubing within the well and the wall of the wellbore or casing.
- Downhole tools such as packers, bridge plugs and frac plugs are often used to seal the annulus formed by a tubing within the well and the wall of the wellbore or casing.
- Downhole tools such as packers, bridge plugs and frac plugs are often used to seal the annulus formed by a tubing within the well and the wall of the wellbore or casing.
- the seal for the annulus is generally established by a deformable element such as rubber or an elastomer.
- a compressive force is generally applied to the deformable element, causing it to extrude radially outward.
- the element extends from the outer portion of the mandrel of the downhole tool to the wellbore wall or casing and seals between those structures.
- Sealing element 10 is illustrated in its first position or unset position.
- Sealing element 10 is shown as being within a wall 42, which can be a casing wall or wellbore wall.
- Sealing element 10 comprises a first sealing member 12 and a second sealing member 14.
- each sealing member is made from a deformable element such as rubber or an elastomeric compound, but can be made of thermoplastic or other various soft deformable materials.
- First sealing member 12 and second sealing member 14 are each disposed about a mandrel 16 of a downhole tool.
- the sealing element 10 is set between a first packer shoe 18 and second packer shoe 20, or between two other barriers at least one of which is moveable so that compression or longitudinal pressure can be applied to the sealing element 10.
- First packer shoe 18 and second packer shoe 20 are also disposed about mandrel 16
- first sealing member 12 is a generally cylindrical sealing element having an outer surface 22, an inner surface 24, a first end 26 and a second end 28. First end 26 abuts first packer shoe 18. Inner surface 24 has an inclined inner wall 30 at second end 28.
- Second sealing member 14 has an outer surface 32, an inner surface 34, a first end 36 and a second end 38. Second sealing member 14 is at least partially wedged or truncated conical in shape so that outer surface 32 has an inclined outer wall 40. Inclined outer wall 40 is at first end 26 of second sealing member 14 and adjacent second end 28 of first sealing member 12 when sealing element 10 is in its unset position. Thus, first sealing member 12 is longitudinally separated from second sealing member 14. By “longitudinally separated” it is meant that the sealing members are spaced longitudinally along mandrel 16 such that there is only a minor portion of overlap or no overlap of the sealing members, that is there is no overlap that creates any significant radial expansion and, preferably, no radial expansion of either sealing member. As shown in FIG.
- second end 38 of second sealing member 14 can be wedged or truncated conical in shape, as shown, or can be another suitable shape such as cylindrical.
- inner surface 24 and inner surface 34 are in contact with mandrel 16 when sealing element 10 is in its unset position.
- outer surface 22 and outer surface 32 are exposed to but spaced away from the wall 42 of the wellbore, which may be a casing wall if the wellbore is lined. Accordingly, neither outer surface 22 nor outer surface 32 are in contact with wall 42.
- sealing element 10 is illustrated in transition from its unset position to its second or set position ( FIG. 3 ) and is illustrated in its set position ( FIG. 4 ).
- first sealing member 12 moves in relation to each other.
- inclined inner wall 30 slides over inclined outer wall 40 causing first sealing member 12 to stretch over second sealing member 14 and come into sealing engagement with wall 42.
- first sealing member 12 moves from being longitudinally spaced from second sealing member 14 to being radially outward from the second sealing member such that outer surface 22 is in sealing engagement with wall 42.
- inner surface 24 of first sealing member 12 is in sealing engagement with outer surface 32 of second sealing member 14, and inner surface 34 of second sealing member 14 is in sealing engagement with mandrel 16.
- Sealing element 10 represents a more versatile sealing element than prior conventional sealing elements. Although designed for a specific casing diameter ("design size") such as that shown in FIGS. 1-4 , sealing element 10 advantageously can also be utilized in smaller diameter casings. As shown in FIG. 5 , when sealing element 10 is used in smaller diameter casing it achieves sealing without the complete overlap of sealing member 12 and sealing member 14. Thus, the amount that first sealing member 12 stretches over second sealing member 14 will be determined by the casing size. As illustrated in FIG.
- first sealing member 12 when used in a casing having a diameter below the design size, first sealing member 12 stretches over second sealing member 14 so that only a first portion 44 of first sealing member 12 is radially outward from second sealing member 14 with the remaining portion or second portion 46 of first sealing member 12 being longitudinally spaced from second sealing member 14.
- outer surface 22 of at least the first portion 44 of first sealing member 14 is in sealing engagement with wall 42 and, depending on the size of the casing, a majority or even all of outer surface 22 can be in sealing engagement with wall 42.
- the inner surface 24 of a second portion 46 of first sealing member 12 is in sealing engagement with mandrel 16 and inner surface 24 of first portion 44 is in sealing engagement with outer surface 32 of second sealing member 14.
- Inner surface 34 of second sealing member 14 is in sealing engagement with mandrel 16.
- FIGS. 6 and 7 the use of an embodiment of the sealing element 10 in a downhole tool 100 is shown. While the embodiment of FIGS. 5 and 6 illustrate downhole tool 100 as a packer tool, it should be understood that the invention is not limited to use in packer-type tools but is useful for any downhole tool for use in a wellbore requiring a fluid tight seal and is especially useful where there is a change in wellbore diameter such that the tool and expansion device must pass through a wellbore of smaller radius before being received into the wellbore where it will be placed in the set position. The latter wellbore having a greater radius than the wellbore of smaller radius.
- downhole tool 100 is shown in well comprising first wellbore or first casing 102 having a diameter D1 and a second wellbore or second casing 104 having a diameter D2.
- D1 is less than D2.
- Downhole tool 100 can be lowered into a well on tubing or can be lowered on a wire line or other means known in the art (not shown).
- FIG. 5 shows the downhole tool 100 in its unset position and
- FIG. 6 shows downhole tool 100 in its set position.
- Downhole tool 100 comprises a mandrel 106 with an outer surface 108 and inner surface 110.
- Mandrel 106 will typically be a drillable material such as a polymeric composite.
- Mandrel 106 has a bore 112 defined by inner surface 110.
- Mandrel 106 has upper or top end 116 and lower or bottom end 118. Bore 112 defines a central flow passage therethrough.
- An end section 120 may comprise a mule shoe 120.
- Mule shoe 120 is shown as integrally formed with the mandrel 106 but can be a separate piece that is connected with pins to mandrel 106.
- Mule shoe 120 defines an upward facing shoulder 122 thereon.
- Mandrel 106 has first or upper outer diameter 130, a second or first-intermediate outer diameter 132, which is a threaded outer diameter 132, a third or second-intermediate outer diameter 134 and a fourth or lower outer diameter 136. Shoulder 122 is defined by and extends between third and fourth outer diameters 134 and 136, respectively. Threads 138 are defined on threaded outer diameter 132. A head or head portion 140 is threadedly connected to mandrel 112 and, thus, has mating buttress threads 142 thereon.
- Head portion 140 has an upper end 144 that may comprise a plug or ball seat 146. Head 140 has lower end 148 and has first, second and third inner diameters 150, 152 and 154, respectively. Buttress threads 142 are defined on third inner diameter 154. Second inner diameter 152 has a magnitude greater than first inner diameter 150 and third inner diameter 154 has a magnitude greater than second inner diameter 152. A shoulder 156 is defined by and extends between first and second inner diameters 150 and 152. Shoulder 156 and upper end 120 of mandrel 106 define an annular space 158 therebetween. In the embodiment illustrated, a spacer sleeve 160 is disposed in annular space 158.
- Spacer sleeve 160 has an open bore 162 so that fluid may pass unobstructed therethrough into and through longitudinal central flow passage 124. Head portion 140 may be disconnected by unthreading from mandrel 106 so that instead of spacer sleeve 160, a plug may be utilized. The plug will prevent flow in either direction and, as such, the tool will act as a bridge plug.
- a spacer ring 164 is disposed about mandrel 106 and abuts lower end 148 of head portion 140 so that it is axially restrained on mandrel 106.
- Downhole tool 100 further comprises a set of expansion apparatuses 166 as described in co-pending US Patent Application Serial Number 14/848,323, filed January 31, 2013 .
- Expansion apparatuses 166 comprise first and second or upper and lower expansion apparatuses 167 and 168.
- Upper and lower expansion apparatuses 167 and 168 are generally identical in configuration but their orientation is reversed on mandrel 106.
- Expansion apparatuses 167 and 168 have slip rings 170.
- Slip rings 170 are segmented slip rings and are shown as having buttons 172 secured to the outer surface thereof. When downhole tool 100 is moved to the set position, as shown in FIG. 6 , buttons 172 will grippingly engage second casing 104 to secure downhole tool 100 in the wellbore.
- Buttons 172 comprise a material of sufficient hardness to partially penetrate second casing 104 and may be comprised of metallic-ceramic composite or other material of sufficient strength.
- Expansion apparatuses 167 and 168 further have expansion wedges 174, which are segmented wedges. Expansion wedges 174 are likewise disposed about mandrel 106. Further, expansion apparatuses 167 and 168 have wedges 176, which are disposed about mandrel 106. Wedges 176 are in contact with expansion wedges 174.
- Sealing element 10 which is an expandable sealing element, as described above, is disposed about mandrel 106 and has first and second sealing members 12 and 14.
- the embodiment illustrates a single sealing element; however, a multiple piece packer configuration can be used.
- First and second sealing members 12 and 14 abut the ends of wedges 176 of upper and lower expansion apparatuses 167 and 168, respectively.
- the downhole tool 100 in FIG. 6 in run-in configuration or unset position, is lowered into (run-in) the well by means of a work string of tubing sections or coupled tubing attached to the upper end 144 of head portion 140.
- a setting tool can be part of the work string.
- the downhole tool 100 in its unset position, fits through first casing 102, which has the smaller diameter of the two casings 102 and 104. Downhole tool 100 is then positioned in second casing 104.
- the setting tool is actuated and it drives spacer ring 164 from its run-in configuration to the set position shown in FIG. 7 .
- Spacer ring 164 as well as other components, such as wedge 176 of upper expansion apparatus 167, can be held in place during run-in by shear pins.
- the axial pressure provided by the setting tool is sufficient to shear the shear pins to allow the components held by the shear pins to move to their set position.
- each expansion apparatus 166 is longitudinally compressed, as is sealing element 10. With sufficient compression and sufficient resultant relative movement among the components of the expansion apparatuses 166 (wedges 176, expansion wedges 174 and slip rings 170) the connections between the wedge segments of expansion wedge 174 are sheared and the connections between the slip segments of slip ring 170 are sheared thus separating the wedge segments from each other and the slip segments from each other.
- FIG. 7 shows the downhole tool 100 in its set position with expansion apparatuses 166 in its expanded configuration and with sealing element 10 sealed against casing 104.
- a sealing element for a downhole tool comprising a first sealing member and a second sealing member.
- the first sealing member engages the second sealing member such that the sealing element has a first position and a second position. In the second position, the first sealing member stretches over the second sealing member.
- the first sealing member can be radially outward from the second sealing member when the sealing element is in the second position.
- the sealing element moves from the first position to the second position under compression or tension.
- the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall. The inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member.
- the sealing element when the sealing element is in the second position, the outer surface of the first sealing member is in sealing engagement with a wall of a wellbore; the inner surface of the first sealing member is in sealing engagement with the outer surface of the second sealing member; and the inner surface of the second member is in sealing engagement with a mandrel of the downhole tool.
- a downhole tool for use in a wellbore comprising a mandrel, a first sealing member and a second sealing member.
- the first sealing member is disposed about the mandrel.
- the second sealing member is disposed about the mandrel.
- the first sealing member is longitudinally separated from the second sealing member when the downhole tool is in the unset position, and the first sealing member is radially outward from the second sealing member when the downhole tool is in the second position.
- the first sealing member stretches over the second sealing member when the downhole tool moves from the unset position to the set position.
- the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall.
- the inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member.
- a servicing tool in a wellbore comprising:
- the first sealing member moves from being longitudinally separated from the second sealing member to being radially outward from the second sealing member. Also, after the first sealing member stretches over the second sealing member, the first sealing member sealingly engages the second sealing member.
- the first sealing member has an inner surface with an inclined inner wall and the second sealing member has an outer surface with an inclined outer wall. The inclined inner wall matches the inclined outer wall so that the first sealing member stretches over the second sealing member by the inclined inner wall moving along the inclined outer wall.
Description
- This invention relates to tools used in oil and gas wellbores. More specifically, the disclosure relates to expansion sealing elements used to prevent fluid flow through an annulus formed by a tubing within the well and the wall of the wellbore or casing.
- In drilling or reworking of oil wells, a great variety of downhole tools are used. Downhole tools such as packers, bridge plugs and frac plugs are often used to seal the annulus formed by a tubing within the well and the wall of the wellbore or casing. For example, but not by way of limitation, it is often desirable to seal tubing or other pipe in the casing of the well when it is desired to pump cement or other slurry down the tubing and force the cement or slurry around the annulus of the tubing or out into a formation.
- The seal for the annulus is generally established by a deformable element such as rubber or an elastomer. A compressive force is generally applied to the deformable element, causing it to extrude radially outward. The element extends from the outer portion of the mandrel of the downhole tool to the wellbore wall or casing and seals between those structures.
- Problems are encountered in the use of downhole tools because of variations in wellbore or casing diameter. Thus, when a downhole tool must be lowered through a smaller casing and sealed in a larger casing below the smaller casing, a sealing element that fits through the smaller casing may be too small to adequately expand to seal the larger size casing. Additionally, a sealing element of adequate size to seal the larger casing may be too large to fit into the smaller casing.
- Thus, while there are a number of sealing elements available, there is a need for further such apparatuses that can meet the needs of different well operations utilizing different casing sizes. A prior art high expansion packer including sealing elements is disclosed in
US 2004/0069502 . - The drawings are provided to illustrate certain aspects of the invention and should not be used to limit or define the invention.
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FIG. 1 is a front view of a sealing element in accordance with one embodiment. The sealing element is in the run-in or unset configuration. -
FIG. 2 is a sectional view of the sealing element ofFIG. 1 . -
FIG. 3 is a sectional view of the sealing element ofFIG. 1 when it is being changed from the unset configuration to a set configuration. -
FIG. 4 is a sectional view of the sealing element ofFIG. 1 in the set configuration. -
FIG. 5 is a sectional view of the sealing element in the set configuration. The sealing element is set in a smaller diameter casing than that shown forFIGS. 1-4 -
FIG. 6 is a partial sectional view of a downhole tool incorporating the sealing element of one embodiment. The downhole tool is shown in its run-in or unset position. -
FIG. 7 is a partial sectional view of the downhole tool ofFIG. 5 shown in its set position. - Referring now to the drawings, wherein like reference numbers are used herein to designate like elements throughout the various views, various embodiments are illustrated and described. The figures are not necessarily drawn to scale, and in some instances the drawings have been exaggerated and/or simplified in places for illustrative purposes only. In the following description, the terms "upper," "upward," "lower," "below," "downhole" and the like, as used herein, shall mean: in relation to the bottom or furthest extent of the surrounding wellbore even though the well or portions of it may be deviated or horizontal. The terms "inwardly" and "outwardly" are directions toward and away from, respectively, the geometric center of a referenced object. Where components of relatively well-known designs are employed, their structure and operation will not be described in detail. One of ordinary skill in the art will appreciate the many possible applications and variations of the present invention based on the following description.
- Referring now to
FIGS. 1 and 2 , asealing element 10 is illustrated in its first position or unset position.Sealing element 10 is shown as being within awall 42, which can be a casing wall or wellbore wall.Sealing element 10 comprises afirst sealing member 12 and asecond sealing member 14. Generally, each sealing member is made from a deformable element such as rubber or an elastomeric compound, but can be made of thermoplastic or other various soft deformable materials. First sealingmember 12 andsecond sealing member 14 are each disposed about amandrel 16 of a downhole tool. Thesealing element 10 is set between afirst packer shoe 18 andsecond packer shoe 20, or between two other barriers at least one of which is moveable so that compression or longitudinal pressure can be applied to thesealing element 10.First packer shoe 18 andsecond packer shoe 20 are also disposed aboutmandrel 16 - As can best be seen from
FIG. 2 ,first sealing member 12 is a generally cylindrical sealing element having anouter surface 22, aninner surface 24, afirst end 26 and asecond end 28.First end 26 abutsfirst packer shoe 18.Inner surface 24 has an inclinedinner wall 30 atsecond end 28. -
Second sealing member 14 has anouter surface 32, aninner surface 34, afirst end 36 and asecond end 38.Second sealing member 14 is at least partially wedged or truncated conical in shape so thatouter surface 32 has an inclinedouter wall 40. Inclinedouter wall 40 is atfirst end 26 ofsecond sealing member 14 and adjacentsecond end 28 offirst sealing member 12 when sealingelement 10 is in its unset position. Thus, first sealingmember 12 is longitudinally separated from second sealingmember 14. By "longitudinally separated" it is meant that the sealing members are spaced longitudinally alongmandrel 16 such that there is only a minor portion of overlap or no overlap of the sealing members, that is there is no overlap that creates any significant radial expansion and, preferably, no radial expansion of either sealing member. As shown inFIG. 2 , inclinedinner wall 30 and inclinedouter wall 40 overlap when sealingelement 10 is in its unset position; however, as will be noted, neither first sealingmember 12 nor second sealingmember 14 have any radial expansion due to the overlap. Additionally,second end 38 ofsecond sealing member 14 can be wedged or truncated conical in shape, as shown, or can be another suitable shape such as cylindrical. - As will be appreciated from
FIG. 2 ,inner surface 24 andinner surface 34 are in contact withmandrel 16 when sealingelement 10 is in its unset position. Also,outer surface 22 andouter surface 32 are exposed to but spaced away from thewall 42 of the wellbore, which may be a casing wall if the wellbore is lined. Accordingly, neitherouter surface 22 norouter surface 32 are in contact withwall 42. - Turning now to
FIGS. 3 and 4 ,sealing element 10 is illustrated in transition from its unset position to its second or set position (FIG. 3 ) and is illustrated in its set position (FIG. 4 ). As will be appreciated from the drawings, aspacker shoes first end 26 of first sealingmember 12 andsecond end 38 of second sealingmember 14, the sealingmembers inner wall 30 slides over inclinedouter wall 40 causingfirst sealing member 12 to stretch oversecond sealing member 14 and come into sealing engagement withwall 42. Thus, during the transition from the unset position to the set position, first sealingmember 12 moves from being longitudinally spaced from second sealingmember 14 to being radially outward from the second sealing member such thatouter surface 22 is in sealing engagement withwall 42. Also, when sealingelement 10 is in its set position,inner surface 24 offirst sealing member 12 is in sealing engagement withouter surface 32 ofsecond sealing member 14, andinner surface 34 ofsecond sealing member 14 is in sealing engagement withmandrel 16. -
Sealing element 10 represents a more versatile sealing element than prior conventional sealing elements. Although designed for a specific casing diameter ("design size") such as that shown inFIGS. 1-4 , sealingelement 10 advantageously can also be utilized in smaller diameter casings. As shown inFIG. 5 , whensealing element 10 is used in smaller diameter casing it achieves sealing without the complete overlap of sealingmember 12 and sealingmember 14. Thus, the amount that first sealingmember 12 stretches over second sealingmember 14 will be determined by the casing size. As illustrated inFIG. 5 , when used in a casing having a diameter below the design size, firstsealing member 12 stretches oversecond sealing member 14 so that only a first portion 44 offirst sealing member 12 is radially outward fromsecond sealing member 14 with the remaining portion orsecond portion 46 offirst sealing member 12 being longitudinally spaced fromsecond sealing member 14. In this position,outer surface 22 of at least the first portion 44 offirst sealing member 14 is in sealing engagement withwall 42 and, depending on the size of the casing, a majority or even all ofouter surface 22 can be in sealing engagement withwall 42. Additionally, theinner surface 24 of asecond portion 46 of first sealingmember 12 is in sealing engagement withmandrel 16 andinner surface 24 of first portion 44 is in sealing engagement withouter surface 32 of second sealingmember 14.Inner surface 34 of second sealingmember 14 is in sealing engagement withmandrel 16. - Turning now to
FIGS. 6 and7 , the use of an embodiment of the sealingelement 10 in adownhole tool 100 is shown. While the embodiment ofFIGS. 5 and6 illustratedownhole tool 100 as a packer tool, it should be understood that the invention is not limited to use in packer-type tools but is useful for any downhole tool for use in a wellbore requiring a fluid tight seal and is especially useful where there is a change in wellbore diameter such that the tool and expansion device must pass through a wellbore of smaller radius before being received into the wellbore where it will be placed in the set position. The latter wellbore having a greater radius than the wellbore of smaller radius. - Accordingly, in
FIGS. 6 and7 ,downhole tool 100 is shown in well comprising first wellbore orfirst casing 102 having a diameter D1 and a second wellbore orsecond casing 104 having a diameter D2. As can bee seen, D1 is less than D2.Downhole tool 100 can be lowered into a well on tubing or can be lowered on a wire line or other means known in the art (not shown).FIG. 5 shows thedownhole tool 100 in its unset position andFIG. 6 showsdownhole tool 100 in its set position. -
Downhole tool 100 comprises amandrel 106 with an outer surface 108 andinner surface 110.Mandrel 106 will typically be a drillable material such as a polymeric composite.Mandrel 106 has abore 112 defined byinner surface 110.Mandrel 106 has upper ortop end 116 and lower orbottom end 118.Bore 112 defines a central flow passage therethrough. Anend section 120 may comprise amule shoe 120.Mule shoe 120 is shown as integrally formed with themandrel 106 but can be a separate piece that is connected with pins tomandrel 106.Mule shoe 120 defines an upward facingshoulder 122 thereon. -
Mandrel 106 has first or upper outer diameter 130, a second or first-intermediateouter diameter 132, which is a threadedouter diameter 132, a third or second-intermediateouter diameter 134 and a fourth or lowerouter diameter 136.Shoulder 122 is defined by and extends between third and fourthouter diameters outer diameter 132. A head orhead portion 140 is threadedly connected tomandrel 112 and, thus, has mating buttress threads 142 thereon. -
Head portion 140 has an upper end 144 that may comprise a plug or ball seat 146.Head 140 haslower end 148 and has first, second and thirdinner diameters inner diameter 154. Secondinner diameter 152 has a magnitude greater than firstinner diameter 150 and thirdinner diameter 154 has a magnitude greater than secondinner diameter 152. Ashoulder 156 is defined by and extends between first and secondinner diameters Shoulder 156 andupper end 120 ofmandrel 106 define an annular space 158 therebetween. In the embodiment illustrated, a spacer sleeve 160 is disposed in annular space 158. Spacer sleeve 160 has anopen bore 162 so that fluid may pass unobstructed therethrough into and through longitudinal central flow passage 124.Head portion 140 may be disconnected by unthreading frommandrel 106 so that instead of spacer sleeve 160, a plug may be utilized. The plug will prevent flow in either direction and, as such, the tool will act as a bridge plug. - A
spacer ring 164 is disposed aboutmandrel 106 and abutslower end 148 ofhead portion 140 so that it is axially restrained onmandrel 106.Downhole tool 100 further comprises a set of expansion apparatuses 166 as described in co-pendingUS Patent Application Serial Number 14/848,323, filed January 31, 2013 - Expansion apparatuses 166 comprise first and second or upper and lower expansion apparatuses 167 and 168. Upper and lower expansion apparatuses 167 and 168 are generally identical in configuration but their orientation is reversed on
mandrel 106. Expansion apparatuses 167 and 168 have slip rings 170. Slip rings 170 are segmented slip rings and are shown as havingbuttons 172 secured to the outer surface thereof. Whendownhole tool 100 is moved to the set position, as shown inFIG. 6 ,buttons 172 will grippingly engagesecond casing 104 to securedownhole tool 100 in the wellbore.Buttons 172 comprise a material of sufficient hardness to partially penetratesecond casing 104 and may be comprised of metallic-ceramic composite or other material of sufficient strength. Expansion apparatuses 167 and 168 further haveexpansion wedges 174, which are segmented wedges.Expansion wedges 174 are likewise disposed aboutmandrel 106. Further, expansion apparatuses 167 and 168 havewedges 176, which are disposed aboutmandrel 106.Wedges 176 are in contact withexpansion wedges 174. - Sealing
element 10, which is an expandable sealing element, as described above, is disposed aboutmandrel 106 and has first andsecond sealing members second sealing members wedges 176 of upper and lower expansion apparatuses 167 and 168, respectively. - In operation, the
downhole tool 100 inFIG. 6 , in run-in configuration or unset position, is lowered into (run-in) the well by means of a work string of tubing sections or coupled tubing attached to the upper end 144 ofhead portion 140. A setting tool can be part of the work string. Thedownhole tool 100, in its unset position, fits throughfirst casing 102, which has the smaller diameter of the twocasings Downhole tool 100 is then positioned insecond casing 104. Whendownhole tool 100 is at a desired depth in the well, the setting tool is actuated and it drivesspacer ring 164 from its run-in configuration to the set position shown inFIG. 7 .Spacer ring 164 as well as other components, such aswedge 176 of upper expansion apparatus 167, can be held in place during run-in by shear pins. The axial pressure provided by the setting tool is sufficient to shear the shear pins to allow the components held by the shear pins to move to their set position. - As the distance between
spacer ring 164 and themule shoe 120 is decreased, each expansion apparatus 166 is longitudinally compressed, as is sealingelement 10. With sufficient compression and sufficient resultant relative movement among the components of the expansion apparatuses 166 (wedges 176,expansion wedges 174 and slip rings 170) the connections between the wedge segments ofexpansion wedge 174 are sheared and the connections between the slip segments ofslip ring 170 are sheared thus separating the wedge segments from each other and the slip segments from each other. - With subsequent relative movement among
wedge 176,expansion wedge 174 andslip ring 170,wedge 176 is slid under wedge segments ofexpansion wedge 174 driving them radially outward to their expanded configuration. Similarly, the wedge segments ofexpansion wedge 174 is slid under the slip segments ofslip ring 170 driving them radially outward to their expanded configuration so thatbuttons 172, or other suitable gripping elements, grippingly engagesecond casing 104. During the reduction in distance betweenspacer ring 164 andmule shoe 120, first sealingmember 12 and second sealingmember 14 are compressed such that first sealingmember 12 is stretched over second sealingmember 14 and first sealingmember 12 seals against thesecond casing 104.FIG. 7 shows thedownhole tool 100 in its set position with expansion apparatuses 166 in its expanded configuration and with sealingelement 10 sealed againstcasing 104. - In accordance with the above description a few exemplary embodiments will now be described. In a first embodiment there is provided a sealing element for a downhole tool, comprising a first sealing member and a second sealing member. The first sealing member engages the second sealing member such that the sealing element has a first position and a second position. In the second position, the first sealing member stretches over the second sealing member. In one aspect of this embodiment, the first sealing member can be radially outward from the second sealing member when the sealing element is in the second position. In another aspect, the sealing element moves from the first position to the second position under compression or tension. Also, the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall. The inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member.
- In a further aspect of this embodiment, when the sealing element is in the second position, the outer surface of the first sealing member is in sealing engagement with a wall of a wellbore; the inner surface of the first sealing member is in sealing engagement with the outer surface of the second sealing member; and the inner surface of the second member is in sealing engagement with a mandrel of the downhole tool.
- In another embodiment, there is provided a downhole tool for use in a wellbore comprising a mandrel, a first sealing member and a second sealing member. The first sealing member is disposed about the mandrel. The second sealing member is disposed about the mandrel. When the downhole tool moves from an unset position to a set position, the first sealing member moves in relation to the second sealing member such that the first sealing member sealingly engages the wellbore. Further, when the downhole tool moves from an unset position to a set position, the first sealing member sealingly engages the second sealing member and the second sealing member sealingly engages the mandrel.
- In a further aspect of this embodiment, the first sealing member is longitudinally separated from the second sealing member when the downhole tool is in the unset position, and the first sealing member is radially outward from the second sealing member when the downhole tool is in the second position.
- In still a further aspect, the first sealing member stretches over the second sealing member when the downhole tool moves from the unset position to the set position. Also, the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall. The inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member. Additionally, when the downhole tool moves from the unset position to the set position, compressive forces can be applied to the first sealing member and to the second sealing member thus moving the first sealing member from being longitudinally separated from the second sealing member to being radially outward from the second sealing member.
- In another embodiment, there is provided a method of operating a servicing tool in a wellbore comprising:
- longitudinally compressing a sealing element along a central axis, wherein the sealing element has a first sealing member and a second sealing member and the compressing results in relative axial movement of the first sealing member and the second sealing member;
- upon sufficient compression, expanding the first sealing member such that it stretches over the second sealing member and sealingly engages the wellbore.
- In a further aspect of this embodiment, during the relative axial movement, the first sealing member moves from being longitudinally separated from the second sealing member to being radially outward from the second sealing member. Also, after the first sealing member stretches over the second sealing member, the first sealing member sealingly engages the second sealing member. In another aspect of this method, the first sealing member has an inner surface with an inclined inner wall and the second sealing member has an outer surface with an inclined outer wall. The inclined inner wall matches the inclined outer wall so that the first sealing member stretches over the second sealing member by the inclined inner wall moving along the inclined outer wall.
- Other embodiments will be apparent to those skilled in the art from a consideration of this specification or practice of the embodiments disclosed herein. Thus, the foregoing specification is considered merely exemplary with the true scope thereof being defined by the following claims.
Claims (13)
- A downhole tool (100) for use in a well having a casing (102), the downhole tool (100) comprising:a mandrel (16,106);a slip ring (170) disposed about said mandrel (16,106), wherein said slip ring (170) has an unset position in which the slip ring (170) does not engage the casing (102) and a set position in which said slip ring (170) grippingly engages the casing (102);a first wedge (176) disposed about said mandrel (16,106), wherein said first wedge (176) is arranged such that relative longitudinal movement of said first wedge (176) towards said slip ring (170) drives said slip ring (170) radially outward to the set position;a second wedge (176); anda sealing element (10) arranged between the first wedge (176) and second wedge (176), the sealing element (10) comprising a first sealing member (12) and a second sealing member (14); characterised in thatthe first sealing member (12) abuts one of the first wedge (176) and second wedge (176);the second sealing member (14) abuts the other of the first wedge (176) and second wedge (176) ; wherein said first sealing member (12) engages said second sealing member (14) such that said sealing element (10) has a first position and a second position, and wherein said first sealing member (12) stretches over said second sealing member (14) when said sealing element (10) is in said second position such that said stretching places the first sealing member (12) in sealing engagement with said casing (102), and wherein said first sealing member (12) and said second sealing member (14) are in operable relation with said first wedge (176) and said second wedge (176) such that longitudinal pressure can be applied to the sealing element (10) to move the sealing element (10) from said first position to said second position.
- A downhole tool as claimed in claim 1, wherein said first sealing member (12) is radially outward from said second sealing member (14) when said sealing element (10) is in said second position.
- A downhole tool as claimed in claim 1, wherein said sealing element (10) moves from said first position to said second position under compression or tension.
- A downhole tool as claimed in claim 3, wherein said first sealing member (12) has an inner surface (24) with an inclined inner wall (30) and said second sealing member (14) has an outer surface (32) with an inclined outer wall (40), and wherein said inclined inner wall (30) matches said inclined outer wall (40) so as to facilitate said stretching of said first sealing member (12).
- A downhole tool as claimed in claim 4, wherein
either(i) when said sealing element (10) is in said second position:
said outer surface (22) of said first sealing member (12) is in sealing engagement with a wall of a wellbore:said inner surface (24) of said first sealing member (12) is in sealing engagement with said outer surface (32) of said second sealing member (14); andsaid inner surface (34) of said second member (14) is in sealing engagement with a mandrel (16,106) of said downhole tool (100);or(ii) said first sealing member (12) is radially outward from said second sealing member (14). - A downhole tool as claimed in claim 1, wherein said first sealing member (12): either (a) is longitudinally separated from said second sealing member (14) when said sealing element (10) is in said first position and wherein said first sealing member (12) is radially outward from said second sealing member (14) when said sealing element (10) is in said second position; or (b) stretches over said second sealing member (14) when said sealing element (10) moves from said first position to said second position.
- A downhole tool as claimed in claim 6, wherein said first sealing member (12) has an inner surface (24) with an inclined inner wall (30) and said second sealing member (14) has an outer surface (32) with inclined outer wall (40), and wherein said inclined inner wall (30) matches said inclined outer wall (40) so as to facilitate said stretching of said first sealing member (12).
- A downhole tool as claimed in claim 7, wherein when said sealing element (10) moves from said first position to said second position, compressive forces are applied to said first sealing member (12) and to said second sealing member (14) thus moving said first sealing member (12) from being longitudinally separated from said second sealing member (14) to being radially outward from said second sealing member (14), optionally wherein, when said sealing element (10) moves from a first position to a second position, said first sealing member (12) sealingly engages said second sealing member (14) and said second sealing member sealingly engages said mandrel (16,106).
- A downhole tool as claimed in claim 1, in which an expansion wedge having wedge segments is disposed about said mandrel, said wedge segments expandable radially outwardly by interaction with the wedge.
- A downhole tool as claimed in any preceding claim, wherein
the first sealing member (12) is disposed about said mandrel (16,106);
the second sealing member (14) is disposed about said mandrel (16,106); and
wherein during movement of the sealing element (10) from the first position to the second position said first sealing member (12) moves in relation to said second sealing member (14) such that said first sealing member (12) slides over said second sealing member (14). - A method of operating a servicing tool in a wellbore comprising:longitudinally compressing a sealing element (10) along a central axis, wherein said sealing element (10) is as claimed in claim 10, and has a first sealing member (12) and a second sealing member (12) and said compressing results in relative axial movement of said first sealing member (12) and said second sealing member (14);upon sufficient compression, expanding said first sealing member (12) such that it stretches over said second sealing member (14) and sealingly engages said wellbore.
- A method as claimed in claim 11, wherein during said relative axial movement said first sealing member (12) moves from being longitudinally separated from said second sealing member (14) to being radially outward from said second sealing member (14).
- A method as claimed in claim 11, wherein, after said first sealing member (12) stretches over said second sealing member (14), said first sealing member (12) sealingly engages said second sealing member (14); and optionally wherein said first sealing member (12) has an inner surface (24) with an inclined inner wall (30) and said second sealing member (14) has an outer surface (34) with an inclined outer wall (40), and wherein said inclined inner wall (30) matches said inclined outer wall (40) so that said first sealing member (12) stretches over said second sealing member (14) by said inclined inner wall (30) moving along said inclined outer wall (40).
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2014/033508 WO2015156796A1 (en) | 2014-04-09 | 2014-04-09 | Sealing element for downhole tool |
Publications (3)
Publication Number | Publication Date |
---|---|
EP3094813A1 EP3094813A1 (en) | 2016-11-23 |
EP3094813A4 EP3094813A4 (en) | 2017-08-16 |
EP3094813B1 true EP3094813B1 (en) | 2019-12-04 |
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Application Number | Title | Priority Date | Filing Date |
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EP14888977.7A Active EP3094813B1 (en) | 2014-04-09 | 2014-04-09 | Sealing element for downhole tool |
Country Status (6)
Country | Link |
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US (1) | US20160265303A1 (en) |
EP (1) | EP3094813B1 (en) |
AU (1) | AU2014390013B2 (en) |
CA (1) | CA2939070C (en) |
MX (1) | MX2016011592A (en) |
WO (1) | WO2015156796A1 (en) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9835003B2 (en) * | 2015-04-18 | 2017-12-05 | Tercel Oilfield Products Usa Llc | Frac plug |
US20200048981A1 (en) * | 2018-08-07 | 2020-02-13 | Petroquip Energy Services, Llp | Frac Plug with Sealing Element Compression Mechanism |
US11162322B2 (en) | 2018-04-05 | 2021-11-02 | Halliburton Energy Services, Inc. | Wellbore isolation device |
WO2019209336A1 (en) * | 2018-04-27 | 2019-10-31 | Halliburton Energy Services, Inc. | Bridge plug with multiple sealing elements |
Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2003008760A1 (en) * | 2001-07-18 | 2003-01-30 | Shell Internationale Research Maatschappij B.V. | Method of sealing an annulus |
Family Cites Families (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6827150B2 (en) * | 2002-10-09 | 2004-12-07 | Weatherford/Lamb, Inc. | High expansion packer |
GB0317547D0 (en) * | 2003-07-26 | 2003-08-27 | Weatherford Lamb | Sealing tubing |
NO325912B1 (en) * | 2005-03-15 | 2008-08-18 | Easy Well Solutions As | Device and method for inserting a bottom seal into a borehole |
GB0515070D0 (en) * | 2005-07-22 | 2005-08-31 | Moyes Peter B | Downhole tool |
US7387158B2 (en) * | 2006-01-18 | 2008-06-17 | Baker Hughes Incorporated | Self energized packer |
GB0802237D0 (en) * | 2008-02-07 | 2008-03-12 | Swellfix Bv | Downhole seal |
US8087459B2 (en) * | 2009-03-31 | 2012-01-03 | Weatherford/Lamb, Inc. | Packer providing multiple seals and having swellable element isolatable from the wellbore |
US20100263876A1 (en) * | 2009-04-21 | 2010-10-21 | Frazier W Lynn | Combination down hole tool |
US9470060B2 (en) * | 2012-09-06 | 2016-10-18 | Weatherford Technology Holdings, Llc | Standoff device for downhole tools using slip elements |
US9004160B2 (en) * | 2013-01-09 | 2015-04-14 | Donald J. Greenlee | Downhole tool apparatus with slip plate and wedge |
-
2014
- 2014-04-09 US US14/766,026 patent/US20160265303A1/en not_active Abandoned
- 2014-04-09 MX MX2016011592A patent/MX2016011592A/en unknown
- 2014-04-09 AU AU2014390013A patent/AU2014390013B2/en not_active Ceased
- 2014-04-09 CA CA2939070A patent/CA2939070C/en active Active
- 2014-04-09 WO PCT/US2014/033508 patent/WO2015156796A1/en active Application Filing
- 2014-04-09 EP EP14888977.7A patent/EP3094813B1/en active Active
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2003008760A1 (en) * | 2001-07-18 | 2003-01-30 | Shell Internationale Research Maatschappij B.V. | Method of sealing an annulus |
Also Published As
Publication number | Publication date |
---|---|
EP3094813A4 (en) | 2017-08-16 |
CA2939070A1 (en) | 2015-10-15 |
AU2014390013A1 (en) | 2016-08-04 |
US20160265303A1 (en) | 2016-09-15 |
AU2014390013B2 (en) | 2018-02-01 |
CA2939070C (en) | 2018-01-23 |
EP3094813A1 (en) | 2016-11-23 |
WO2015156796A1 (en) | 2015-10-15 |
MX2016011592A (en) | 2016-11-29 |
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