GB2280461A - Hydraulically set packer - Google Patents
Hydraulically set packer Download PDFInfo
- Publication number
- GB2280461A GB2280461A GB9414953A GB9414953A GB2280461A GB 2280461 A GB2280461 A GB 2280461A GB 9414953 A GB9414953 A GB 9414953A GB 9414953 A GB9414953 A GB 9414953A GB 2280461 A GB2280461 A GB 2280461A
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- Prior art keywords
- bore
- casing
- anchor slip
- mandrel
- packer
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- 230000000712 assembly Effects 0.000 claims abstract description 43
- 238000000429 assembly Methods 0.000 claims abstract description 43
- 230000000452 restraining effect Effects 0.000 claims abstract 2
- 125000006850 spacer group Chemical group 0.000 claims description 17
- 238000000034 method Methods 0.000 claims description 5
- 239000012530 fluid Substances 0.000 description 25
- 238000004519 manufacturing process Methods 0.000 description 13
- 238000010008 shearing Methods 0.000 description 6
- 230000004888 barrier function Effects 0.000 description 4
- 238000001125 extrusion Methods 0.000 description 4
- 238000007789 sealing Methods 0.000 description 4
- 230000002028 premature Effects 0.000 description 3
- 230000009471 action Effects 0.000 description 2
- 238000004873 anchoring Methods 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- 238000012856 packing Methods 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 229910001369 Brass Inorganic materials 0.000 description 1
- 241001246312 Otis Species 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000010951 brass Substances 0.000 description 1
- 230000000295 complement effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000003801 milling Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
- E21B33/1295—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/128—Packers; Plugs with a member expanded radially by axial pressure
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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)
- Piles And Underground Anchors (AREA)
- Containers And Plastic Fillers For Packaging (AREA)
- Packaging Of Annular Or Rod-Shaped Articles, Wearing Apparel, Cassettes, Or The Like (AREA)
Abstract
A hydraulic well packer (10) adapted for positioning within a casing string located in a well bore includes a tubular body mandrel (12), spaced upper (28) and lower (48) anchor slip assemblies and a seal assembly (40) positioned between the anchor slip assemblies. The packer is adapted to disjunctively extend the anchor slip assemblies (28, 48) against the casing after the seal assembly (40) is compressed against the casing, while restraining longitudinal movement of the packer mandrel (12) in the casing against further hydraulic pressure required to fully set the packer. <IMAGE>
Description
HYDRAULICALLY SET PACKER
The present invention relates to a well packer which is hydraulically set or anchored at a downhole location within a well bore by fluid pressure.
In the course of treating and preparing subterranean oil and gas wells for production, a well packer along with a production seal unit are run into the well on a work string, with the packer being set against a casing bore. During run-in, the packer is mechanically locked in the unset condition by shear pins. The packer may be set in the sealing/anchoring configuration by application of hydraulic pressure applied through the work string. With retrievable packers, the packer may be released from the set configuration and retrieved from the well by appropriate manipulation of the tubing string and use of a specially designed pulling tool. With permanent packers, the packer may be released from the set configuration by milling and then retrieved with a suitable fishing tool.
The purpose of the packer is to support production tubing and equipment such as a screen of safety valve adjacent to a producing formation and to seal the annulus between the outside of the production tubing and the inside of the well casing to prevent movement of fluids through the annulus past the packer. In order to retain the packer in position within the well casing, the packer is provided with slip anchor members having opposed camming surfaces which cooperate with complementary opposed wedging surfaces, whereby the slip anchor members are extendable radially into gripping engagement against the well casing bore in response to relative axial movement of the wedging surfaces. The packer also carries resilient seal elements which expand radially into sealing engagement against the bore of the well casing in response to axial compression forces.
Longitudinal movement of the packer components which set the anchor slip and the sealing elements may be effected either hydraulically or mechanically.
In some completions, it is desirable to set packers in tandem or land the packer on a liner top prior to setting. In hydraulically set packer devices which have a seal assembly positioned between a pair of spaced anchor assemblies, it may be necessary for the mandrel of the packer to move longitudinally within the casing against hydraulic pressure in order for the packer to fully set.
However, with such hydraulically set packers when it is desirable to set packers in tandem or land the packer on a liner top prior to setting, which will ordinarily restrict downward movement of the packer mandrel, the packer may not be able to fully set, which may adversely affect both the ability of the packer to anchor the tubing string and its ability to hold pressure. Thus, it is desirable to provide a hydraulically set packer which will overcome this problem, and which allows packers to be set in tandem or landed on a liner top prior to setting.
We have now devised a hydraulically set packer which can be set in tandem or landed on a liner top prior to setting.
According to the present invention, there is provided a well packer adapted for positioning within a casing string located in a well bore, the packer comprising in combination: a tubular body mandrel having a longitudinal flow passage; a pair of spaced anchor slip assemblies mounted on said mandrel, said anchor slip assemblies being movable to a position to engage against the casing bore: a seal assembly mounted on said mandrel between said anchor slip assemblies; said seal assembly being compressible radially outward; piston means included with said mandrel and movable between a first position and a second position to compress said seal assembly radially outward to sealingly engage against the casing bore and move said anchor slip assemblies to a position to engage against the casing bore to retain said mandrel in position in the casing string; and means for allowing said seal assembly to compress radially outward against the casing bore and said anchor slip assemblies to move to a position to engage against the casing bore while said mandrel remains stationary in the casing string.
The well packer according to the present invention includes a tubular body mandrel, a pair of spaced, upper and lower anchor slip assemblies and a seal assembly positioned between the anchor slip assemblies. A movable piston positioned in a bore in the mandrel moves the seal assembly and slip assemblies from a first run in position suitable for running into the well bore to a second set position, wherein the seal assembly sealingly engages against the casing and the slip assemblies are sequentially extended against the casing. Each anchor assembly includes a wedge portion, a slip support, and an anchor slip portion disposed between the wedge portion and slip support. Movement of the wedge portion under the influence of piston movement toward the slip support causes the anchor slip portion to move over the wedge portion and ramp or extend radially outward to engage against the casing.Movement of the upper anchor slip portion against the casing locks the packer mandrel in position in the casing, and prevents longitudinal movement of the packer mandrel within the casing against the application of further hydraulic pressure required in order for the packer to fully set.
A sleeve member is connected to the lower slip support for movement therewith. The sleeve member spaces the lower slip support apart from the lower wedge portion and prevents the radial extension of the lower anchor slip portion until the seal assembly is compressed against the casing bore and the upper slip portion is extended radially outward to engage against the casing bore, thus retaining the packer mandrel in position in the well bore.
Consequently, the application of further hydraulic pressure necessary to assure the seal assembly is sealingly compressed against the casing bore and cause the lower anchor slip portion to ramp radially outward to engage against the casing bore is prevented from causing the mandrel from moving longitudinally downward in the casing string. Thus, the present invention provides a hydraulically set packer apparatus which allows packers to be set in tandem or landed on a liner top prior to setting.
Further application of hydraulic pressure after the seal assembly is compressed against the casing and the upper slip portion is extended radially outward against the casing bore, causes the sleeve member to release from the lower slip support. Release of the sleeve member from the lower slip support allows the lower slip support to move toward the lower wedge portion. The movement of the lower slip support toward the lower wedge portion causes the lower anchor slip portion to move over the lower wedge portion and extend radially outward to engage against the casing, thus allowing the packer to fully set.
The above and other features of the present invention will become apparent from the drawings, the description given herein, and the appended claims.
In order that the invention may be more fully understood, embodiments thereof will be described, by way of example only, with reference to the accompanying drawings, wherein:
Figs. 1A and 1B show a cut-away side view of one embodiment of packer according to the present invention;
Figs. 2A and 2B show a cut-away side view of the packer of Fig. 1, with the packer in a first position in the bore of a casing string;
Figs. 3A and 3B show a second cut-away side view of the packer of Fig. 1, with the packer in a second position with the seal element compressed radially outward against the bore of the casing;
Figs. 4A and 4B show a third cut-away side view of the packer of Fig. 1, with the packer in a third position with its upper slip extended radially outward against the bore of the casing; and
Figs. 5A and 5B show a fourth cut-away side view of the packer of Fig. 1, with the packer in a fourth position with its lower slip extended radially outward against the bore of the casing.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
The well packer 10 is shown in Figs. 1A-1B prior to installation within a well bore. The various components and elements which comprises packer 10 are attached to and carried by a mandrel 12. For ease of manufacturing, mandrel 12 includes various sections, which are concentrically engaged with each other by appropriate threaded connections. The various sections of mandrel 12 include head 18 and bottom sub 22, described hereafter. Mandrel 12 is basically a long, cylindrical tubular body 14 with a bore 16 extending therethrough. As shown in the Figs., bore 16 may be provided with an enlarged upper, counterbored section 17 into which a seal assembly may be disposed.
Mandrel 12 may be provided with a cylindrical head 18, which includes internal threads 20 for connecting packer 10 to a production tubing string (not shown).
Alternatively, mandrel 12 may be provided with a head which is adapted for connecting to a lugged member, or other suitable head which is adapted for connecting to the production tubing string. Conventionally, head 18 may be threadedly attached to the upper end of mandrel 12. An annular seal (not shown) or other conventional sealing means between head 18 and tubular body 14 prevents fluid communication between the annulus 80 formed between packer 10 and casing 74 and mandrel bore 16.
Attached to the lower end of tubular body 14 is a bottom sub 22. As indicated in the Figs., bottom sub 22 may include a conventional box end connector 24 at its lower end, which is internally threaded at 26 for connecting to the threaded pin end of the production component located below packer 10. Tubular body 14 of mandrel 12 carries the upper anchor slip assembly 28, lower anchor slip assembly 48, spacer member 56 and seal assembly 40 as hereafter described. The length of tubular body 14 is selected to be compatible with the required setting stroke of packer 10.
Slidably carried on the exterior of mandrel 12 is an upper anchor slip assembly 28. Upper slip assembly 28 includes an expandable C shaped anchor slip member 30, a cylindrically shaped slip support 32, which may be formed integral with head 18, and a longitudinally movable, cylindrically shaped wedge member 34. As shown in the Figs., slip member 30 may be equipped with teeth 35 on their outer surfaces for gripping casing 74 to hold packer 10 in a fixed position thereto. Alternatively, for example, slip member 30 may be segmented. Wedge member 34 is movable longitudinally toward slip support 32 by the action of piston 62, hereafter described.Slip member 30 moves or ramps outward over wedge member 34 under the influence of piston 62, from its first or relaxed position as shown in Figs. 1A and 2A, and expands radially outward to a position suitable for gripping engagement against the bore 72 of casing 74, as shown in Fig. 4A. Because anchor slip member 30 abuts against top slip support 32, which forms a portion of mandrel 12, movement of slip member 30 to its second position against the bore 72 of casing 74 prevents longitudinal movement of mandrel 12 in the casing string 74 against the application of further hydraulic pressure. A plurality of shearable elements in the form of shear pins 86, described in detail hereafter, releasably engage upper wedge member 34 to the tubular body portion 14 of mandrel 12 until after packer 10 has reached the downhole location.
Slip member 30 and slip support 32 are provided with a plurality of spaced, axially aligned slots 36, best shown in Fig. 1A. Located in each slot 36 may be an elongated key 38, which is adapted to move freely in its slot as slip member 30 moves from its first, relaxed position to its second position. For economy, only one key 38 may be provided. In the event that it is necessary to remove packer 10 from the well bore, keys 38 prevent head 18 from rotating, thus allowing head 18 to be milled down to slip member 30. The remains of packer 10 may now be retrieved with a suitable fishing tool.
An annular seal assembly 40 is slidably disposed on the exterior of mandrel 12 adjacent to upper wedge member 34. Seal assembly 40 comprises anti-extrusion rings or backup shoes 42, 44 and a plurality of annular packing elements 46. Generally, packing elements 46 are formed of a resilient rubber-like material which may be compressed or stressed by forces exerted at opposite ends of elements 46 to effect lateral or radial expansion so that the elements 46 will form a seal in the annulus 80 between the external surface of tubular body 14 of the mandrel 12 and the internal surface of the casing 74, as shown in Fig. 3A, which is confined between upper and lower back up shoes 42, 44.
Preferably, each of the back up shoes 42, 44 may be constructed of a deformable metal such as brass which will shape upon contact with the inner surface or bore 72 of casing 74 to conform to the configuration of the surface. The back up shoes 42, 44 function to prevent extrusion of seal elements 46 as seal elements 46 are compressed sealingly against casing bore 72. It is within the scope of the invention that various alternative packer seal assemblies can also be satisfactorily used with the present invention, such as, for example, a seal assembly as described in U.S. Pat. No. 5,117,906, assigned to Otis
Engineering Corporation.
A lower slip assembly 48 is slidably disposed on the exterior of mandrel 12 adjacent to seal assembly 40. Lower slip assembly 48 includes an expandable C shaped anchor slip member 50, a longitudinally movable, cylindrically shaped slip support 52 and a longitudinally movable, cylindrically shaped wedge member 54. As shown in the Figs., slip member 50 may be equipped with teeth 55 on their outer surfaces for gripping casing 74 to hold packer 10 in a fixed position thereto. Alternately, for example, slip member 50 may be segmented. Slip support 52 is movable toward wedge member 54 by the action of piston 62, hereafter described.Slip member 50 moves or ramps outward over wedge member 54 under the influence of piston 62, from its first or relaxed position as shown in Figs. 1A and 2A, and expands radially outward to a position suitable for gripping engagement against the casing bore 72, as shown in Fig. 5A.
One or more shearable elements in the form of shear pins 82, described in detail hereafter, releasably engage lower slip support 52 to the tubular body portion 14 of mandrel 12 until after packer 10 has reached the downhole location and prevent the rotation of slip support 52 to prevent slip support 52 from moving relative to piston 62.
A plurality of shearable elements in the form of shear pins 85, described in detail hereafter, likewise releasably engage lower wedge member 54 to the tubular body portion 14 of mandrel 12 until after packer 10 has reached the downhole location.
A cylindrical sleeve or spacer member 56 is slidably disposed on the exterior of mandrel 12 between wedge member 54 and bottom slip support 52 to prevent the ramping movement of slip member 50 radially outward against the casing bore 72. Sleeve 56 is releasably connected to bottom slip support 52 by means of a plurality of shearable elements in the form of shear pins 84, described hereafter, which cooperate with sleeve 56 to prevent the movement of bottom slip support 52 toward wedge member 54 until after seal elements 46 of seal assembly 40 are compressed radially outward against the casing bore 72 and upper anchor slip member 30 of the upper anchor slip assembly 28 is moved to a position to engage against the casing bore 72, thus retaining mandrel 12 in position in the casing string 74 to prevent longitudinal movement of the mandrel under the influence of further hydraulic pressure acting upon piston 62.
In order to prevent the movement of bottom slip support 52 toward wedge member 54 until after seal elements 46 of seal assembly 40 are compressed radially outward against the casing bore 72 and upper anchor slip member 30 of the upper anchor slip assembly 28 is moved to a position to engage against the casing bore 72, shear pins 84 are shearable at a predetermined pressure, which is higher than the predetermined pressure at which shear pins 78, 82, 85 and 86 shear. As may be appreciated, the total shear value for shear pins 84 may be 19,140 pounds, which may be provided by six shear pins, each having a shear value of 3,190 pounds.Of course, those skilled in the art will see that the value at which shear pins 84 may shear may be selected to assure that seal elements are fully compressed against casing bore 72 to assure a leak-proof seal is formed before lower anchor slip member 50 is ramped radially outward against the casing bore 72.
Slip support 52 is provided with an elongated, annular recess 58 into which sleeve 56 recedes when shear pins 84 shear, thus allowing slip support 52 to pass over sleeve 56 and move toward wedge member 54 to cause slip member 50 to ramp radially outward over wedge member 54 against the casing bore 72. Together, sleeve or spacer member 56 and shear pins 84 provide a sequential means for causing the anchor slip assemblies to move independently.
Alternatively, the sequential means may be in the form of a cylindrical, lugged sleeve member. In this embodiment, the sleeve member includes a lug which interlocks in a notched recess groove located on the bottom of the lower slip support, which allows the lugged sleeve member to move under the influence of piston 62 concurrently with the lower slip support. After moving a predetermined distance, the lugs spring inwardly into a recess on the mandrel body, thus disengaging the lug from the notched groove on the slip support to allow piston 62 to move the lower slip support toward the lower wedge member, thus causing slip member 50 to ramp radially outward against the casing bore 72.The sequential means may also be in the form of a cylindrical, collet fingered sleeve member in which the fingers recede inwardly to interlock into a recess on the mandrel body after the sleeve has moved a predetermined distance to release the slip support for movement toward the wedge member to cause the anchor slip member 50 to ramp radially outward against the casing bore.
Located in an annular recess 60 formed between bottom sub 22 and tubular body 14 is a cylindrical piston 62. Piston 62 includes an elongated extension 64 which is connected to lower slip support 52 via threads or the like for movement therewith. A plurality of shearable elements in the form of shear screws or pins 78, discussed hereafter, releasably engage piston 62 to bottom sub 22 until after packer 10 has reached the desired downhole location. As will be explained later, fluid pressure from mandrel bore 16 can be applied to piston 62 to move slip support 52 longitudinally along mandrel 12. Piston 62 is movable from a first position, as shown in Figs. lA-lB and 2A-2B to a second position, as shown in Figs. 5A-5B.The movement of piston 62 from its first position to its second position compresses seal elements 46 radially outward against the casing bore 72, thereby forming a fluid barrier with the inner wall or bore 72 of casing string 74 as shown in Fig. 3A, and sequentially ramps upper and lower anchor slip members 30, 50 radially outward against the casing string 74, as shown in Figs. 4A and
SA.
A pair of annular elastomeric seals 66 carried on opposite sides of piston 62 form a movable fluid barrier between tubular body 14, piston 62 and bottom sub 22. Piston 62 and elastomeric seals 66 enclose a variable volume fluid chamber 68, which is provided by the annular recess 60 formed between tubular body 14 and bottom sub 22. Ports 70 extend radially through tubular body 14 to allow fluid communication between bore 16 of mandrel 12 and fluid chamber 68 during the setting of packer 10. Seals 66 also isolate the bore 16 of mandrel 12 from the annulus 80 formed between packer 10 and casing string 74 and mandrel bore 16. As may be appreciated, the number of seal elements or other seal means between piston 62, tubular body 14 and bottom sub 22 which enclose fluid chamber 68 may number more or less.
In Figs. lA-lB, well packer 10 is shown prior to installation within bore 72 of casing 74. Using standard well completion techniques, well packer 10 can be attached by threads 20 to a production tubing string at the well surface (not shown) and lowered through bore 72 to the desired downhole location within casing 74, as shown in Figs. 2A2B. A plurality of shearable elements in the form of pins (not shown) retained in bores 76 in head 18 connect with the lower end of the production tubing string to prevent the premature disconnection of the tubing string from head 18. A ball (not shown), for example, dropped from the well surface via the tubing string engages and cooperates with a ball catcher (not shown) located below ports 70 to form a barrier against downward fluid flow through mandrel bore 16. Alternatively, the ball may be inserted into the ball catcher prior to lowering well packer 10. As may be appreciated, the ball catcher may be arranged such that upward flow can lift the ball out of engagement with the ball catcher to assure fluid pressure below the ball is not greater than the fluid pressure in the bore 16 of mandrel 12. It is within the scope of the invention that other arrangements other than the before mentioned ball and catcher device may alternatively be used to form a temporary barrier against downward fluid flow through mandrel bore 16.
When packer 10 is at its desired location, increased fluid pressure from the well surface is supplied to mandrel bore 16 via the production tubing string, where it is communicated to variable volume fluid chamber 68 via radial ports 70 to act against piston 62. As the fluid pressure above the ball increases, the shear value of shear screws 78 is selected to release piston 62 for movement before any other components of well packer 10 move. As may be appreciated the shear value of shear screws 78 is such to prevent inadvertent shearing of screws 78 from a higher pressure in mandrel bore 16 than the pressure present in the annulus 80 formed between packer 10 and casing 74 before procedures to set well packer 10 have begun. As may be appreciated, the combined shear value for shear screws 78 may be 10,000 pounds.As screws 78 shear, one or move shearable elements in the form of shear pins 82 shear also. As may be appreciated the shear value of shear pins 82 is such that lower slip support 52 is prevented from rotating and unscrewing from piston 62 while well packer 10 is being lowered to its desired location in the well bore, thus preventing premature shearing of shear pins 84, 85 or 86.
As may be appreciated, the total shear value for shear pins 82 may be 1,790 pounds, which may be provided by one shear pin. Shearing screws 78 and pins 82 allows piston 62, extension 64 and lower slip support 52 to begin to move upward from their first position shown in Figs. 2A-2B, causing sleeve 56 to abut against the lower edge of lower wedge member 54.
In order to prevent lower anchor slip member 50 from prematurely ramping radially outward against the casing bore 72 before upper anchor slip member 30 is ramped radially outward against the casing bore 72 and seal elements 46 are compressed sealingly against the bore 72 of casing 74, a plurality of shearable elements in the form of shear pins 84 are provided which have a shear value that is selected which is higher than the shear value of shear pins 78, 82, 85 or 86. As may be appreciated, before their predetermined shearing value is reached, shear pins 84 connect sleeve 56 to lower slip support 52 for movement therewith and prevent the movement of lower slip support 52 relative to sleeve 56 to retain the spacing between lower slip support 52 and lower wedge member 54 once sleeve 56 abuts against lower wedge member 54.Thus, shear pins 84 provide releasable means for connecting sleeve 56 to lower slip support 52. As may be appreciated, the total shear value for shear pins 84 may be 19,140 pounds, which may be provided by six shear pins, each having a shear value of 3,190 pounds. Of course, those skilled in the art will see that the value at which shear pins 84 may shear may be selected to assure that seal elements are fully compressed against casing bore 72 to assure a leakproof seal is formed before lower anchor slip member 50 is ramped radially outward against the casing bore 72.
After screws 78 and pins 82 shear, increased fluid pressure from the well surface is supplied to mandrel bore 16 and communicated through radial bores 70 to chamber 68 to act further against piston 62, thus causing shearable elements in the form of shear pins 85, which are selected to shear at a predetermined value which may be greater or less than the value at which pins 78, 82 shear and which may be less than, greater than or equal to the value necessary to cause pins 86 to shear. As may be appreciated, the total shear value for shear pins 85 may be 10,740 pounds, which may be provided by six shear pins, each having a shear value of 1,790 pounds.Once shear pins 85 shear, piston 62 continues to move upward to compress seal elements 46 sealingly against the bore 72 of casing 74, as shown in Figs. 3A-3B, thus isolating the annulus 80A above seal elements 46 from the annulus 80B below seal elements 46. Compression of seal elements 46 against the bore 72 of casing 74 causes anti-extrusion shoes 42, 44 to engage against bore 72 to prevent the annular extrusion of seal elements 46. Generally, as seal elements 46 are compressed against the casing bore 72, backup shoes 42, 44 may rotate fully against wedge members 34, 54. As may be appreciated the shear value of shear pins 86 is such to avoid premature shearing before seal elements 46 engage against bore 72.
After shear pins 85 shear, further increased fluid pressure from the well surface is supplied to mandrel bore 16 and communicated through radial bores 70 to chamber 68 to act against piston 62, thus causing shearable elements in the form of shear pins 86 to shear. In order to have seal elements 46 compressed against casing bore 72 before upper anchor slip member 30 is ramped radially outward against casing bore 72, shear pins 86 are selected to have a predetermined value which is sufficient to prevent their shearing before elements 46 are compressed against the casing bore 72. As may be appreciated, the total shear value for shear pins 86 may be 10,740 pounds, which may be provided by six shear pins, each having a shear value of 1,790 pounds.With a shear value of 10,740 pounds, it is thus assured that 10,740 pounds of compressive force is applied against elements 46 to compress seal elements 46 against the casing bore 72 before pins 86 shear.
Once shear pins 86 have sheared, continued upward movement of piston 62 will cause upper wedge 34 to move upward toward upper slip support 32 and under anchor slip member 30, thus causing upper anchor slip member 30 to ramp radially outward against the bore 72 of casing 74, as shown in Figs. 4A4B.
Because upper slip support is functionally part of mandrel 12, once upper anchor slip member 30 is engaged against bore 72 of casing 74, longitudinal movement of mandrel 12 downward under the influence of fluid pressure communicated via ports 70 to variable volume fluid chamber 68, which acts downward against lower shoulder portions 88 of bottom sub 22, is prevented.This has the advantage in that further increased fluid pressure supplied to mandrel bore 16 which is: (1) communicated to variable volume fluid chamber 68 to act against piston 62, thus moving piston 62, and lower wedge member 54 further upward against seal elements 46 to assure seal elements 46 are sealingly engaged against bore 72 of casing 74, and (2) necessary to cause shear pins 84 to finally shear; and which acts downward against lower shoulder portions 88 does not cause mandrel 12 to move downward. Thus, in well completions where movement of the packer mandrel downward is restricted by setting packers in tandem or by landing the packer on a liner top prior to setting, the packer 10 of the present invention is provided with the capability of setting fully, even should the packers be set in tandem or the packer landed on a liner top or other restriction prior to setting.Of course, packer 10 may be used in other types of completions, where mandrel movement is not ordinarily restricted.
After shear pins 86 shear, further increased fluid pressure from the well surface is supplied to mandrel bore 16 and communicated through radial bores 70 to chamber 68 to act further against piston 62, thus causing shear pins 84 to shear. In order to have upper anchor slip member 30 ramped radially outward against casing bore 72 to prevent downward longitudinal motion of mandrel 12 in casing 74 and seal elements 46 fully compressed against casing bore 72, shear pins 84 are selected to have a predetermined value which is higher than the predetermined values at which shear pins 78, 82, 85 and 86 shear. As stated above, the total shear value for shear pins 84 may be 19,140 pounds, which assures that 19,140 pounds of compressive force is applied against elements 46 to compress seal elements 46 against the casing bore 72 before pins 84 shear. Once shear pins 84 have sheared, continued upward movement of piston 62 will cause lower slip support 52 to move upward over sleeve 56 and toward lower wedge member 54, thus causing lower anchor slip member 50 to move upward over wedge member 54 and ramp radially outward against the bore 72 of casing 74, as shown in Figs. 5A-5B. As lower slip support 52 moves over sleeve 56 toward lower wedge member 54, sleeve 56 recedes into annular recess 60.
Located in a wedge shaped recess 90 formed on the lower end of lower slip support 52 between lower slip support 52 and tubular body 14 is an internal slip member 92. Internal slip member 92 is arranged to allow upward movement of lower slip support 52 relative to tubular body 14 so that seal elements 56 can be compressed against casing bore, and anchor slip members 30, 50 ramped radially outward against the casing bore 72 while preventing downward movement of lower slip support 52 relative to tubular body 14. A C-clip or lock ring 94 located in an annular groove on lower slip support 52 retains internal slip member 92 within recess 90 for concurrent movement with lower slip support 52.Consequently, when internal slip member 92 is moved to the position shown in Figs 5A-5B, lower slip support 52 is locked against downward movement and well packer 10 is anchored in the set position, with the upper annulus 80A isolated from the lower annulus 80B. As may be appreciated, by continuing to increase the fluid pressure above the ball, sufficient force is generated to allow the ball to be pumped downward through the ball catcher and out the lower end of the production component located below packer 10. Unrestricted flow can occur in either direction through mandrel bore 16 after removal of the ball.
Should it be desired to remove well packer 10 from the well bore, the top of well packer 10 may be milled to release slip member 30, which will allow the seal assembly 40 and upper and lower slip assemblies 28, 48 to relax. As head 18 is milled down to slip member 30, keys 38 prevent head 18 from rotating. Once head 18 is milled down to slip member 30, the remains of packer 10 may now be retrieved with a suitable fishing tool.
Those skilled in the art will see that the present invention readily allows packer 10 to be used with anchoring means other than anchor slip members 30 and 50. Further, in order to support heavy hang weight below well packer 10, it may be necessary to increase the wall thickness of mandrel section 14, head 18 and bottom sub 22 and their respective
threaded connections. If desired, the lower end of bottom sub 22 or the production
component located therebelow may be provided with a centralizer.
While the invention has been particularly shown and described with reference to
the preferred embodiments, it will be understood by those skilled in the art that various
modifications and changes in form and detail may be made.
Claims (29)
1. A well packer adapted for positioning within a casing string located in a well bore, the packer comprising in combination: a tubular body mandrel having a longitudinal flow passage; a pair of spaced anchor slip assemblies mounted on said mandrel; said anchor slip assemblies being movable to a position to engage against the casing bore; a seal assembly mounted on said mandrel between said anchor slip assemblies, said seal assembly being compressible radially outward; piston means included with said mandrel and movable between a first position and a second position to compress said seal assembly radially outward to sealingly engage against the casing bore and move said anchor slip assemblies to a position to engage against the casing bore to retain said mandrel in position in the casing string; and means for allowing said seal assembly to compress radially outward against the casing bore and said anchor slip assemblies to move to a position to engage against the casing bore while said mandrel remains stationary in the casing string.
2. A packer according to claim 1, wherein said means for allowing said seal assembly to compress radially outward against the casing bore and said anchor slip assemblies to move to a position to engage against the casing bore while said mandrel remains stationary in the casing string includes sequential means for causing said anchor slip assemblies to move independently to sequentially engage against the casing bore.
3. A packer according to claim 2, wherein said anchor slip assemblies are connected with said mandrel so that the movement of one of said anchor slip assemblies to a position to engage against the casing bore causes said mandrel to remain stationary in the casing string while said piston means sequentially moves the other anchor slip assembly to d position to engage against the casing bore.
4. A packer according to claim 1, 2 or 3, wherein said anchor slip assemblies comprise an upper anchor slip assembly and a lower anchor slip assembly, and wherein said movement means is arranged to move said upper anchor slip assembly to a position to engage against the casing bore before said lower anchor slip assembly.
5. A packer according to claim 4, wherein said upper anchor slip assembly is attached to said mandrel to prevent longitudinal motion of said mandrel in the casing string when said upper anchor slip assembly is moved to a position to engage against the casing bore.
6. A packer according to claim 2 or 3, wherein each anchor slip assembly includes a segmented anchor member and an adjacent wedge means, said anchor member being movable over said wedge means by the movement of said piston means from a first position radially outward to a second position against the casing bore.
7. A packer according to claim 6, wherein said sequential means includes sleeve means arranged between said piston means and one of said wedge means to retain the spacing between said wedge means and said piston means, said sleeve means being movable with said piston means to restrain concurrent movement of both anchor members radially outward to their second position while allowing the independent movement of one anchor member radially outward over its adjacent wedge means to its second position against the casing bore, and releasable means for releasing said sleeve means from movement with said piston means at a predetermined pressure to allow the radial outward movement of the other anchor member over its adjacent wedge means to its second position against the casing bore.
8. A packer according to claim 7, wherein said packer further comprises releasable means for connecting said sleeve means to said piston means for movement therewith.
9. A packer according to claim 7, wherein said releasable means is a shear pin, which shears at said predetermined pressure to disconnect said sleeve means from said piston means.
10. A well packer adapted for positioning within a casing string located in a well bore, comprising in combination; a tubular body mandrel having a longitudinal flow passage; a pair of upper and lower anchor slip assemblies mounted on said mandrel; said upper and lower anchor slip assemblies being adapted for independent movement to a position to grippingly engage against the casing bore; a seal assembly mounted on said mandrel between said upper and lower anchor slip assemblies, said seal assembly being compressible radially outward; piston means included with said mandrel and movable between a first position and a second position to compress said seal assembly radially outward to sealingly engage against the casing bore and extend said anchor slip assemblies radially outward into gripping engagement against the casing bore to retain said mandrel in position in the casing and; means for causing said upper anchor slip assembly to move to a position to grippingly engage against the casing bore before said lower anchor slip assembly is moved to a position to grippingly engage against the casing bore.
11. The well packer of claim 10, wherein said means for causing said upper anchor slip assembly to move to a position to grippingly engage against the casing bore before said lower anchor slip assembly is moved to a position to grippingly engage against the casing bore includes a spacer member that is connected with said lower anchor slip assembly from moving to a position to engage against the casing string before said upper anchor slip assembly is moved to a position to grippingly engage against the casing bore.
12. The well packer of claim 11, wherein said packer further comprises means for releasing said spacer member from said lower anchor slip assembly to allow said lower anchor slip assembly to move to a position to engage against the casing bore after said upper anchor slip assembly is moved to a position to engage against the casing string.
13. The well packer of claim 12, wherein said means for releasing said spacer member from said lower anchor slip assembly, releases said spacer member after said seal assembly is compressed radially outward and said upper anchor slip assembly is moved to a position to engage against the casing string.
14. The well packer of claim 12, wherein said means for releasing is a shear pin which connects said spacer member with said piston means for movement therewith and which shears at a predetermined value to disconnect said spacer member from said spacer member to allow further movement of said piston means to move said lower anchor slip assembly to a position to engage against the casing string.
15. The well packer of claim 10, wherein said upper anchor slip assembly is connected to said mandrel to prevent longitudinal motion of said mandrel in said casing string when said upper anchor slip assembly is moved to a position to grippingly engage against the casing bore.
16. The well packer of claim 10, wherein each of said anchor slip assemblies includes a wedge portion, a slip support, and an anchor slip portion disposed between said wedge portion and said slip support, said wedge portion and said slip support being adapted for movement toward each other, said anchor slip portion being movable over said wedge portion as said slip support and said wedge portion move toward each other, the movement of said anchor slip portion over said wedge portion causing said anchor slip portion to extend radially outward and gripping engage against the casing bore.
17. Packer apparatus positionable in the bore of a casing string located in a well bore, comprising: a tubular body mandrel having a longitudinal flow passage; an upper anchor slip assembly mounted on said mandrel; a lower anchor slip assembly mounted on said mandrel in a spaced relationship to said upper anchor slip assembly; a seal assembly mounted on said mandrel between said anchor slip assemblies; piston means included with said mandrel and movable between a first position and a second position to compress said seal assembly radially outward to sealingly engage against the casing bore and move said anchor slip assemblies to a position to engage against the casing bore; and means for sequentially moving said anchor slip assemblies to a position to grippingly engage against the casing bore after said seal assembly is compressed sealingly against the casing bore.
18. The packer apparatus of claim 17, wherein said means for sequentially moving said anchor slip assemblies to a position to grippingly engage against the casing bore after said seal assembly is compressed sealingly against the casing bore includes a spacer member that is connected with said lower anchor slip assembly for movement therewith to prevent said lower anchor slip assembly from moving to a position to engage against the casing string before said seal means is compressed radially outward to sealingly engage against the casing bore and until said upper anchor slip assembly is moved to a position to grippingly engage against the casing bore.
19. The packer apparatus of claim 18, wherein said packer further comprises means for releasing said spacer member from said lower anchor slip assembly to allow said lower anchor slip assembly to move to a position to engage against the casing bore after said seal means is compressed radially outward to sealingly engage against the casing bore and said upper anchor slip assembly is moved to a position to grippingly engage against the casing bore.
20. The packer apparatus of claim 19, wherein said means for releasing is a shear pin which connects said spacer member with said piston means for movement therewith and which shears at a predetermined value to disconnect said spacer member from said spacer member to allow further movement of said piston means to move said lower anchor slip assembly to a position to engage against the casing string.
21. The packer apparatus of claim 17, wherein said upper anchor slip assembly is connected to said mandrel to prevent longitudinal motion of said mandrel in said casing string when said upper slip assembly is moved to a position to grippingly engage against the casing bore.
22. The packer apparatus of claim 17, wherein each of said anchor slip assemblies includes a wedge portion, a slip support, and an anchor slip portion disposed between said wedge portion and said slip support, said wedge portion and said slip support being adapted for movement toward each other, said anchor slip portion being movable over said wedge portion as said slip support and said wedge portion move toward each other, the movement of said anchor slip portion over said wedge portion causing said anchor slip portion to extend radially outward and gripping engage against the casing bore.
23. A well packer adapted for positioning within a casing string located in a well bore, comprising in combination: a tubular body mandrel having a longitudinal flow passage; a pair of spaced, upper and lower anchor slip assemblies mounted on said mandrel, said anchor slip assemblies being movable to a position to engage against the casing string; a seal assembly mounted on said mandrel between said anchor slip assemblies, said seal assembly being compressible radially outward; piston means included with said mandrel and movable between a first position and a second position to compress said seal assembly radially outward to sealingly engage against the casing bore and move said anchor slip assemblies to a position to engage against the casing string; and a spacer member connected to said lower anchor slip assembly movement therewith to prevent said lower anchor slip assembly from moving to a position to engage against the casing string; and means for releasing said spacer member from said lower anchor slip assembly to allow said lower anchor slip assembly to move to a position to engage against the casing string after said seal assembly is compressed radially outward and said upper anchor slip assembly is moved to a position to engage against the casing string.
24. The well packer of claim 23, wherein said upper slip assembly is connected to said mandrel to retain said mandrel in a stationary position when said upper slip assembly is moved to a position to engage against the casing string.
25. The well packer of claim 23, wherein said means for releasing is a shear pin which shears at a predetermined value.
26. A method of setting a packer in the bore of a casing string located in a well bore, comprising the steps of: forming a seal against the bore of the casing string to isolate the bore of the casing string above the seal from the bore of the casing string below the seal; and disjunctively moving a pair of anchor slip assemblies mounted on the mandrel of the packer to a position to grippingly engage against the bore of the casing string.
27. A method of setting a packer in the bore of a casing string located in a well bore, comprising the steps of: sequentially moving a pair of anchor slip assemblies mounted on the mandrel of the packer to a position to grippingly engage against the bore of the casing string while restraining longitudinal movement of the packer mandrel: and forming a seal against the bore of the casing string to isolate the bore of the casing string above the seal from the bore of the casing string below the seal before both anchor assemblies are moved to a position to grippingly engage against the bore of the casing string.
28. A well packer substantially as herein described with reference to the accompanying drawings.
29. A method of setting a packer in the bore of a casing string substantially as herein described with reference to the accompanying drawings.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US9764293A | 1993-07-26 | 1993-07-26 |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| GB9414953D0 GB9414953D0 (en) | 1994-09-14 |
| GB2280461A true GB2280461A (en) | 1995-02-01 |
Family
ID=22264429
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB9414953A Withdrawn GB2280461A (en) | 1993-07-26 | 1994-07-25 | Hydraulically set packer |
Country Status (2)
| Country | Link |
|---|---|
| GB (1) | GB2280461A (en) |
| NO (1) | NO942767L (en) |
Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2321918B (en) * | 1996-11-14 | 2000-12-13 | Halliburton Energy Serv Inc | Backup shoe |
| WO2005106189A1 (en) * | 2004-05-05 | 2005-11-10 | Specialised Petroleum Services Group Limited | Improved packer |
| US7789137B2 (en) | 2001-06-27 | 2010-09-07 | Weatherford/Lamb, Inc. | Non-metallic mandrel and element system |
| CN102425392A (en) * | 2011-12-27 | 2012-04-25 | 中国石油集团西部钻探工程有限公司 | Hydraulic sealing permanent packer |
| WO2014015469A1 (en) * | 2012-07-23 | 2014-01-30 | 思达斯易能源技术(集团)有限公司 | Liner hanger top packer |
| CN110259407A (en) * | 2019-07-16 | 2019-09-20 | 中国石油化工股份有限公司 | A kind of machine liquid inner-lock-type compression packer |
| US11078754B2 (en) | 2016-10-10 | 2021-08-03 | Ardyne Holdings Limited | Downhole test tool and method of use |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102979471B (en) * | 2012-12-10 | 2015-08-19 | 中国石油集团西部钻探工程有限公司 | Anticreep distinguish slip hydraulic hanging packer |
| CN112943153B (en) * | 2019-12-11 | 2022-10-04 | 中国石油天然气股份有限公司 | But deblocking doublestage hydraulic cylinder formula linkage |
| CN111075389B (en) * | 2020-03-01 | 2024-04-30 | 长江大学 | Packer with radial support function |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB1025779A (en) * | 1963-09-13 | 1966-04-14 | Camco Inc | Well packer assembly for subsurface well working equipment |
| GB1161081A (en) * | 1965-08-16 | 1969-08-13 | Otis Eng Co | Well Tools. |
| GB2086962A (en) * | 1980-11-07 | 1982-05-19 | Dresser Ind Imc | Well tools |
| US4397351A (en) * | 1979-05-02 | 1983-08-09 | The Dow Chemical Company | Packer tool for use in a wellbore |
| US4457369A (en) * | 1980-12-17 | 1984-07-03 | Otis Engineering Corporation | Packer for high temperature high pressure wells |
-
1994
- 1994-07-25 GB GB9414953A patent/GB2280461A/en not_active Withdrawn
- 1994-07-25 NO NO942767A patent/NO942767L/en unknown
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB1025779A (en) * | 1963-09-13 | 1966-04-14 | Camco Inc | Well packer assembly for subsurface well working equipment |
| GB1161081A (en) * | 1965-08-16 | 1969-08-13 | Otis Eng Co | Well Tools. |
| US4397351A (en) * | 1979-05-02 | 1983-08-09 | The Dow Chemical Company | Packer tool for use in a wellbore |
| GB2086962A (en) * | 1980-11-07 | 1982-05-19 | Dresser Ind Imc | Well tools |
| US4457369A (en) * | 1980-12-17 | 1984-07-03 | Otis Engineering Corporation | Packer for high temperature high pressure wells |
Cited By (16)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2321918B (en) * | 1996-11-14 | 2000-12-13 | Halliburton Energy Serv Inc | Backup shoe |
| US7789137B2 (en) | 2001-06-27 | 2010-09-07 | Weatherford/Lamb, Inc. | Non-metallic mandrel and element system |
| WO2005106189A1 (en) * | 2004-05-05 | 2005-11-10 | Specialised Petroleum Services Group Limited | Improved packer |
| GB2428066A (en) * | 2004-05-05 | 2007-01-17 | Specialised Petroleum Serv Ltd | Improved packer |
| EA009758B1 (en) * | 2004-05-05 | 2008-04-28 | Спешилайзд Петролеум Сервисиз Груп Лимитед | Improved packer |
| GB2428066B (en) * | 2004-05-05 | 2008-12-10 | Specialised Petroleum Serv Ltd | Improved packer |
| US7510016B2 (en) | 2004-05-05 | 2009-03-31 | Specialised Petroleum Services Group Limited | Packer |
| CN102425392B (en) * | 2011-12-27 | 2014-07-30 | 中国石油集团西部钻探工程有限公司 | Hydraulic sealing permanent packer |
| CN102425392A (en) * | 2011-12-27 | 2012-04-25 | 中国石油集团西部钻探工程有限公司 | Hydraulic sealing permanent packer |
| WO2014015469A1 (en) * | 2012-07-23 | 2014-01-30 | 思达斯易能源技术(集团)有限公司 | Liner hanger top packer |
| EA026625B1 (en) * | 2012-07-23 | 2017-04-28 | Старс Энерджи Энд Текнолоджи (Груп) Ко., Лтд. | Liner hanger top packer |
| US9745809B2 (en) | 2012-07-23 | 2017-08-29 | Starse Energy And Technology (Group) Co., Ltd. | Liner hanger top packer |
| US11078754B2 (en) | 2016-10-10 | 2021-08-03 | Ardyne Holdings Limited | Downhole test tool and method of use |
| US11180973B2 (en) | 2016-10-10 | 2021-11-23 | Ardyne Holdings Limited | Downhole test tool and method of use |
| CN110259407A (en) * | 2019-07-16 | 2019-09-20 | 中国石油化工股份有限公司 | A kind of machine liquid inner-lock-type compression packer |
| CN110259407B (en) * | 2019-07-16 | 2021-06-15 | 中国石油化工股份有限公司 | Mechanical-hydraulic internal locking compression packer |
Also Published As
| Publication number | Publication date |
|---|---|
| NO942767D0 (en) | 1994-07-25 |
| GB9414953D0 (en) | 1994-09-14 |
| NO942767L (en) | 1995-01-27 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| WAP | Application withdrawn, taken to be withdrawn or refused ** after publication under section 16(1) |