US3851705A - Dual hydraulically actuated oil well packer - Google Patents

Dual hydraulically actuated oil well packer Download PDF

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Publication number
US3851705A
US3851705A US00412386A US41238673A US3851705A US 3851705 A US3851705 A US 3851705A US 00412386 A US00412386 A US 00412386A US 41238673 A US41238673 A US 41238673A US 3851705 A US3851705 A US 3851705A
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United States
Prior art keywords
packer
mandrels
anchor
slip
piston
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Expired - Lifetime
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US00412386A
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English (en)
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M Jett
D Spriggs
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Dresser Industries Inc
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Dresser Industries Inc
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Priority to US00412386A priority Critical patent/US3851705A/en
Priority to CA208,792A priority patent/CA1002449A/en
Priority to US504010A priority patent/US3915261A/en
Priority to GB40884/74A priority patent/GB1483072A/en
Priority to GB7923/77A priority patent/GB1483073A/en
Priority to DE2452433A priority patent/DE2452433C3/de
Application granted granted Critical
Publication of US3851705A publication Critical patent/US3851705A/en
Anticipated expiration legal-status Critical
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/122—Multiple string packers
    • 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

Definitions

  • ABSTRACT A simplified and efficient dual string hydraulically actuated packer assembly is disclosed which utilizes unitary tubular anchor means, compressible packer elements, and springloaded, shearable, ratcheting packer lock means.
  • FIG. 1 A first figure.
  • multi-string packers include the inflatable or bladder type such as disclosed in US. Pat. No. 2,991,833 and the hydraulically actuated, compressible element, multi-string packer such as disclosed in U.S. Pat. No. 3,167,127. All known multi-string packers using mechanical anchors to lock the assembly to the casing wall utilize the wedge-type slip segments having teeth which are cammed or wedged into contact with the casing wall by the action of a wedging mandrel being forced inside the slip segments forcing them outwardly into contact with the casing.
  • buttons include the hydraulic button type which are spring-retained radial pistons slidably located in the wall of the packer body and actuated outwardly against the spring retainer by hydraulic force applied from inside the packer assembly.
  • An example of the button type slips is shown in US. Pat. No. 3,31l,l69.
  • the dual-string or dual-conduit packers normally are used with a standard single string packer located on the tubing string below the dual-packer, which tubing string communicates with a lower formation below the standard packer and is connected to one conduit in the dual packer and from there to a tubing string passing to the surface.
  • the second formation is normally located between the standard packer and the dual packer and can be produced through the second conduit pass-. ing through the dual packer and communicating with a second tubing string extending to the surface.
  • the present invention comprises a dual string packer having simplified design, shortened length, and highly efficient tubular unitary slip means.
  • FIG. I is a top view of the dual packer assembly
  • FIG. 5 shows an axial cross-sectional view of the assembly taken at line 5-5 of FIG. 2;
  • FIG. 6 is across-section side view of the improved unitary tubular slip
  • FIG. 7 is a top view of the improved unitary slip
  • FIG. 7a is a side view of the improved unitary slip
  • FIG. 8 illustrates a cross-sectional view of the apparatus in its engaged position
  • FIG. 9 illustrates the top view of an alternate embodiment of the apparatus
  • FIGS. 10A through 10C comprise a cross-sectional view of the embodiment of FIG. 9 taken at line 10-10 in FIG. 8;
  • FIGS. 11a through He are cross-sectional views of the embodiment of FIG. 9 taken at line 1l-l1;
  • FIG. 11d is a cross-sectional axial view of a key retaining sleeve
  • FIG. ll la is a side cross-sectional view of a key retaining sleeve
  • FIG. 11f is an axial end view of a retaining key
  • FIGS. 12A through 12C comprise a cross-sectional view of the embodiment of FIG. 9 taken at line l212 of FIG. 9;
  • FIG. 13 is an isometric view of the shearable ratchet pins
  • FIG. 14 is an isometric view of one of the setting cylinder releasing keys in the piston assembly
  • FIGS. 15a and 15b are schematic cross-sectional views of the gripping teeth on the anchor slip.
  • FIGS. 16a and 16b show axial and radial crosssectional views of the wedge-cone heads disassembled from the apparatus
  • FIG. 17 illustrates a cross-sectional view of the slip of the second embodiment
  • FIG. 18 shows a side view of the slip of FIG. 17
  • FIG. 19 is an axial cross-sectional view of a mandrel locking assembly
  • FIG. 20 is a lateral cross-sectional side view of the mechanism of FIG. 19 taken at line 20-20;
  • FIG. 21 is a lateral cross-sectional top view of the mechanism of FIG. 19 taken at line 212l.
  • FIGS. 1 through 5 A preferred embodiment of the invention is illustrated in FIGS. 1 through 5 in which a packer assembly 1 is comprised of an upper mandrel assembly head 2,
  • a receiver collar 12 is connected by bolts 13 to mandrel head 9 and has bore passages 10b and 11b coinciding and axially aligned with passages 10 and 11 of head 9.
  • Collar 12 has a concave cupped upper surface 12a arranged to guide a tubing string connector 14 into bore 11b of the assembly.
  • Mandrel head 9 further has a threaded internal section 10c adapted toreceive a section of conduit-or tubing in threaded engagement therein.
  • Tubular mandrels 7 and 8 fixedly attached by threaded connection to head 9, extend in parallel relationship to the longitudinal axis of the packer assembly 1 and generally parallel to the well-bore and have bottom threaded sections 7a and 80 extending downward out of the piston assembly 6 whereby either or both may be threadedly engaged into a lower tubing string extending downward into the wellbore.
  • Upper and lower packer heads 31 and 33 are metal cylindrical plates having a cupped surface on one side and having two axial bores therethrough for receiving mandrels 7 and 3.
  • Resilient packer elements 32 are made of a resilient material such as synthetic rubber and are generally cylindrical, with dual bore passages passing axially therethrough to snugly receive mandrels 7 and 8. Packer elements 32 are located in close fitting relationship with each other and with the cupped surfaces of plates 31 and 33. A flanged retainer ring 341 abutting an external shoulder 16 on mandrel 8 limits downward movement of the resilient packer assembly 3 on the mandrels by also abutting the lower surface of lower head 33.
  • Lower unitary slip is located on the mandrels in encircling relationship about the mandrels and slidably mounted thereon; slip 5 is similar to slip 4 but is mounted on the mandrels in an inverted orientation to slip 4.
  • Piston assembly 6 is mounted on mandrels 7 and 8 in encircling relationship and consists of cylindrical setting piston 61 and cylindrical setting cylinder 62.
  • Setting piston 61 is a substantially solid cylindrical piece having dual axial bore passages therethrough to receive mandrels 7 and 8 and an upper annular space 63 around mandrel 8.
  • setting piston 61 as shown in cross-section, has a plurality of transverse lateral cylindrical bore passages 64 intersecting the longitudinal axis of bore passage 11 and having internal helical threads.
  • Shearable cylindrical ratchet pins 65 are slidably located in passages 64 and are urged into engagement with mandrel 8 by the expansive forces of leaf, helical, or belleville springs 66 which are held in compression against pins 65 by abutting engagement with threaded plugs 67 which are snugly secured into threaded passages 64.
  • Pins 65 have a reduced section 65a designed to shear at a predetermined load and a toothed ratchet head 65b having a curved face adapted to match the curvature of mandrel 8, with a plurality of cammed teeth 65c thereon designed to match and engage external annular teeth 8b formed on mandrel 8.
  • FIG. 13 illustrates a second view of the shearable ratchet pins showing the relationship of the teeth 650 on ratchet head 65b.
  • the teeth 8b and those on head 65 are arranged to allow upward movement of the pins on mandrel 8 but prevent downward movement of the pins and thus prevent downward movement of piston 61.
  • teeth 8b and 650 allow the piston 61 to move upward by camming the pins back against the springs 66, compressing them and allowing the ratchet teeth to slide over one another.
  • the perpendicular faces of teeth 65c abut the perpendicular faces of teeth 8b and prevent the backward motion. Further operation and function of the ratcheting arrangement will be described in connection with operation of the entire packer assembly.
  • Setting cylinder 62 is a cylindrical element having a substantially solid'lower section 62a and an upwardly extending outer collar 62b passing exteriorly around piston 61.
  • Lower section 62a is solid except for two longitudinal bore passages therethrough which receive in snug slidable relationship the mandrels 7 and 8.
  • Cylinder 62 is temporarily attached to piston 61 by means of a plurality of shear pins 68 passing through upper collar 62b in threaded engagement therewith and seating in exterior channel 61a passing circumferentially around piston 61.
  • Setting cylinder 62 is temporarily attached to mandrel 8 by means of a plurality of curved locking keys 69 having inwardly projecting shoulder 69a thereon for engaging a matching exterior channel in mandrel 8. Keys 69 are held inward by overlapping abutment of annular shoulder 61b on the lower end of piston 61.
  • the keys by abutment with the grooved channel in mandrel 8, the lower end of piston 61, and the upper end of solid end 62a of cylinder 62 temporarily prevent any sliding motion of the piston assembly 6 with respect to mandrels 7 and 8.
  • One or more ports are located through the wall of mandrel 8 to communicate with the area between piston 61 and cylinder end 62a from bore 11 to release keys 69 in a manner which will be more fully described in relation to the operation of this tool.
  • a standard threaded collar 19 attached thereto containing a valve seat 21 for receiving a fluid valve member such as a ball or plug, arranged to selectively close passage 11 to fluid flow through mandrel 8 and allow fluidic pressure to be applied through ports 80.
  • tubing string connector 14 is more particularly described as a cylindrical tubular upper sleeve 14c having internal threads 14a for engaging a standard conduit section and an annular external depression 14b for receiving a seal carrier ring 15.
  • a lower spring collet sleeve 16 is threadedly attached at 16a to the upper sleeve 14c and has collar 16b thereon for abutting and retaining carrier ring 15 which has a plurality of circular seals 17 thereon for sealing engagement between connector 14 and head 9.
  • Collet sleeve 16 is temporarily restrained in head 9 by the abutment of annular exterior shoulder 16c with interior annular projection 9a in head 9. Removal of shoulder 16c upward past projection 9a can be accomplished by application of a predetermined lifting force which causes inward deflection of the shoulder 16c and allows it to move upward past projection 9a. Deflection inward of shoulder is made possible by the forming of several longitudinal slots 16d in collet sleeve 16 thereby lending flexibility to the metal remaining in the areas between the slots. The amount of lifting force required to move collet sleeve 16 out of head 9 can be adjusted as desired by the number and/or width of slots 16d and/or the angle of engagement between 160 and 9a.
  • Each slip 4 and 5 comprises a generally cylindrical gripping unit having on the extended outer reaches of opposing sides a plurality of teeth 41 curved about the slip body with an axis of curvature at an angle to the central longitudinal axis of the slip member.
  • the teeth are also arranged so that the intersection of a plane passing through theslip longitudinal axis with the teeth extreme outer tips would circumscribe a curve as shown in FIGS. a and 15b. This is to allow the use of this apparatus in casings having varying inner diameters and obviates the need for a separate set of unitary slips for each weight rating of easing.
  • the curved boundary tooth profile as shown in FIGS. 15a and 15b allows this versatility of use by providing greater tooth-casing wall contact area regardless of which teeth are called upon to anchor the packer assembly.
  • each unitary slip has a dual-axis bore passage for each mandrel to pass therethrough.
  • One axis of each bore passage generally parallels the central longitudinal axis of the slip and the other axis is located at an angle thereto in the same plane.
  • FIG. 6 the intersecting bore passages are illustrated more clearly and their longitudinal axes are designated as XX and Y--Y. This view is taken from the side with the two mandrels lying in line with one another so that only one can be seen in cross section.
  • the axis X-X defines bore passages 43 which are shown by 1 the dashed lines in the figure.
  • the angle between axes XX and Y-Y can be from 5 up to about 35 but preferably is around 18 to 20?.
  • FIG. 6 a significant improvement in the unitary anchor slip 5 is illustrated-in the cross-sectional view which shows the abutment surface 51. This surface is at the opposite end of the slip from abutment edge 52 and provides a dual purpose surface on the slip.
  • Rotation of the slip into casing engagement is achieved'by moving an abutment means such as piston 61 against compound surface 51 which moves the slip along the mandrel until abutment edge 52 encounters an opposing abutment surface.
  • the resultant effect is a rotational moment established in the slip from the reactant force on edge 52. This is aided by abutment forces introduced into the slip from surface 51.
  • Surface 51 has been termed a dual or compound surface. This is because of the flat portion 51a and the tangentially curved section 51b joining the flat surface.
  • the curve of surface 51b is preferably on a radius R substantially equivalent to rL where L is the axial length of the slip along axis XX.
  • the curved surface is tangential to flat surface 51a at the point where axis -X-X intersects the end of the slip at surface 51.
  • the slip is arranged to pivot about a point C located at the intersection of axes X-X and Y-Y at a distance of approximately ra of the slip length L from surface 51.
  • a phantom line P is drawn on the slip at the edge containing surface 51b to indicate the construction of the prior art slip means.
  • Such a slip is disclosed in US. Pat. No. 3,739,849 to Robert B. Meripol. While the slip of that disclosure is a significant improvement over the art, the existence of the extended shoulder P requires significant additional apparatus in the packer on which it is used.
  • the improved slip of this invention eliminates the need for the supporting sleeve, the pivot pins, and the pivot clearance necessary to the prior art device.
  • Another advantage of the improved slip is in the guaranteed setting of the slip.
  • the clearance below the slip ever be decreased due to stretching of the parts, accumulated debris in the clearance area, failure of one or more of the parts, or incorrect assembly of the tool during manufacture, to-the point where the clearance is substantially less than the amount Rp L, it is clear that edge P will abut the lower surface or the debris in opposition to the setting forces at edge 52 and the desired rotational moment about C will be cancelled.
  • One further advantage of the improved slip is that, when used as the lower slip, should it become lodged in the casing to the point that the releasing spring 4% hereinafter described is insufficient to rotate it out of engagement, dislodgement can be accomplished by merely bumping upward on the slip with the lower abutment means. Since some point on the curved surface 5lb will be located directly below C and will receive the upward abutment it is clear that no rotational moment will be introduced into the slip, and the simple upward driving force, in addition to the disengaging force of the releasing spring 49b will dislodge the slip from the casing. The upper surface 52 will of course be free from abutment during this releasing step.
  • slip 5 has been described above, it is emphasized that slip 4 is identical to slip 5 and operates in the same manner, and the above description appertains thereto as well.
  • these two side-by-side ,dual bore passages and the compound curved-flat abutment surface 51 allow the unitary slip to pivot about the two parallel mandrels 7 and 8 from a non-engaging position to a casing contact position without any interference between the slips and the mandrels.
  • Each slip also has a releasing slot 46 as shown in FIG. 3 which runs partially the length of the slip and passes through the wall thereof in a plane perpendicular to the plane of the two dual-axis bore passages and the central slip axis.
  • a third bore passage 47 passes from the inner terminal wall 460 of the slot 46 through the slip to the opposite end.
  • the cross-sectional view of FIG. 3 reveals the purpose of slot 46 and passage 47 to be for the location of the threaded L-shaped releasing lug 48 and release spring 48a in the upper slip 4; and in the lower slip 5, retaining bolt 49, flanged bolt collar 49a, and
  • a spring cavity 490 is formed in each slip and a spring cavity 48b is formed in the L-shaped bolt to receive coil spring 48a.
  • Lug 48 passes through passage 67 and is threadedly secured into the lower end of head 9.
  • bolt 49 passes through passage 47 of the lower slip 5 and is threadedly secured to the upper end of setting position 61.
  • FIGS. 2 through 5 the packer assembly is illus- I trated in its unset orientation with the mandrels 7 and 8 lying in bore passages 43 parallel to the central longitudinalaxis.
  • FIG. 8 the packer apparatus has been activated and expanded into sealing and anchoring engagement with the casing wall. In this position, the slips have been rotated to bring the mandrels into the second bore passages 44 at the angle to the longitudinal bore passages 43 mentioned above.
  • packer apparatus 1 is lowered into the well until the lower packer passes the upper producing formation and is situated between the two subject formations.
  • the packer apparatus 1 will be located above the upper producing formation.
  • the lower packer is set in the casing.
  • the lower packer may be set by wireline or other means before the primary and secondary tubing strings are lowered into the hole and then the primary string can be stung into the lower packer.
  • the second production string may then be lowered down the well with the connector sleeve 14 threadedly attached at the lower end. When the string has been lowered sufficiently, the sleeve 14 will engage head 9 and snap into place. The second string will then be sealingly communicating with mandrel 8 via bore 11 of head 9.-
  • a sealing ball or plug 20 is dropped run in on a wireline, or pumped into the secondary tubing string to seal on seat 21 and allow fluid pressure to be applied to the fluid in the secondary string and act through bore 11 and ports 80 against the lower end of the setting piston 61.
  • piston 61 will shear pins 68 and move upward against the lower edge 51 of lower slip 5 sliding the slip upward until upper abutment edge 52 of the slip contacts the lower edge of lower head 33. Movement upward of piston 61 on mandrel 8 is allowed by the ratcheting action of ratchet pins 65 over mandrel teeth 8b which ratchet mechanism simultaneously prevents downward movement of piston 61 on mandrel 8 under normal operating conditions.
  • ratchet pins 65 will maintain mandrel 8 telescoped within piston 61 thereby preventing the packer from unsetting should mandrel 8 try to move upward in the wellbore for any reason.
  • a relatively soft filler material such as lead or plastic can be filled in the gap at 65a to absorb the bending moment and insure proper shearing of the pins.
  • the apparatus of this invention must be used in a well having extremely high formation pressures or used in treatments of wells whereby fluids under high pressure must be pumped into the well formations through this apparatus.
  • pressures below the above described packer assembly may reach the range of 5000 PSI or higher, and in this range a considerable upward force is exerted by the fluid upon the conduit strings in the wellbore, creating a buoyancy effect on the packer mandrels tending to drive them upward through the packer assembly resulting in unsetting of the slips and consequently the packer elements.
  • This buoyancy effect is termed the piston" or end area effect.
  • a special locking mechanism is provided which is actuated by pressure below the packer elements and serves to lock the mandrels in the packer assembly.
  • FIG. 19 is an axial view in crosssection taken at line 19-19 of FIG. 20.
  • the packer assembly 3 of FIGS. 1-4 is replaced by the modified locking packer assembly 203.
  • Packer assembly 203 consists essentially of an upper head 231, resilient packer elements 232 and lower head 233, all encircling mandrel 7 and modified mandrel 208.
  • Modified mandrel 208 is substantially similar to mandrel 8 except for theexistence of a plurality of tooth ridges 210 formed in the outer surface of the mandrel.
  • Each ridge 210 has an abrupt upper face 210a and a sloping lower face 210b.
  • the angle that face 210a makes with a plane normal to the tubular axis of mandrel 208 is preferably about ten degrees butmay vary from one to forty degrees depending upon the amount of restraining force desired.
  • the angle of face 210! with face 210a may be from l30 to about 50 with a preferable angle of around 90.
  • Ridges 210 preferably circle mandrel 208 entirely but this is not absolutely essential.
  • the packer assembly 203 contains two fluid bore passages 204 and 205 passing through lower head 233, resilient packer elements 232, and part of the way into upper head 231.
  • the bore passages generally run parallel to the mandrels 7 and 208 and communicate with the formation annular area below the packer assembly 203.
  • Rigid tubes 206 and 207 line the bores through the resilient elements 232 to prevent collapse and closure of the passages upon compression and deformation of the resilient packer elements.
  • the bore passages 204 and 205 intersect pin channels 211 and 212 passing from the-longitudinal bore passage 209 in head 231 containing mandrel 208, going radially outward from mandrel 208 through head 231 and through the outer surface of the head.
  • the radial passages 211 and 212 contain outer threaded portions 211a and 212a and smooth piston sections 2l1b and 212b.
  • the radial passages preferably are of a cylindrical configuration for ease and convenience of manufacture but may be of any reasonable configuration.
  • locking pistons 213 and 214 Located slidably in piston sections 211b and 212b of the radial passages are locking pistons 213 and 214 having curved toothed faces 213a and 2140.
  • the teeth on these faces match and complement the teeth of mandrel 208 so that full surface contact between the two sets of teeth will occur.
  • the radius of curvature of faces 213a and 214a is substantially equal to that of the outer surface of mandrel 208.
  • Threaded sections 211a and 212a contain threaded plugs 215 and 216 snugly engaged therein in sealing contact, which plugs, in conjunction with pistons 213 and 214, serve to form hydraulic expansion chambers 217 and 218 in each radial passage.
  • Circular seals 219 and 220 in the outer wall of pistons 213 and 214 serve to prevent leakage of fluid from the expansion chambers into the mandrel bore passage 209.
  • Operation of the locking mechanism is automatic when this modified embodiment of packer mechanism 203 is installed in the previously described packer apparatus 1, and consists of hydraulic pressure from the annular area below the packer mechanism 203 communicating through bores 204 and 205 and into pressure actuation chambers 217 and 218.
  • the pressure is prevented from moving radially outward by plugs 215 and 216 and therefore it acts inwardly against the pistons 213 and 214 driving them against the mandrel teeth 210 thereby gripping the mandrel 208 and holding it in the packer assembly 203.
  • the angle of faces 210a on the mandrel teeth should be around five to fifteen degrees to allow upward movement of the mandrels upon application of external lifting force on the mandrels.
  • the pressure area of piston faces 213 and 214 may be designed so that the gripping force of the piston teeth on the mandrel teeth is just equalto or slightly greater than the buoyant upward force on the mandrels so that little additional upward lifting of the mandrels is required to wedge the piston teeth out of engagement with the mandrel teeth when unsetting the packer to remove it from the wellbore.
  • the back or lower edges 2101) of the mandrel teeth are at a relatively flat angle compared to the upper faces 210a so that movement of the upper head upward on the mandrels is hardly impeded.
  • FIGS. 9 through 12 and 16 through 18 an alternate embodiment of the invention is disclosed which utilizes a single unitary slip or anchor capable of anchoring the assembly in the casing against upward and downward forces and pressures.
  • the packer apparatus 101 essentially comprises upper connector assembly 102, upper head assembly 103, packer assembly 104, unitary slip 105, and piston assembly 106.
  • the upper connector assembly 102 features a primary tubing receiver 110 which is an elongated tubular member having external threads 1100 and 110b at its upper and lower ends and containing a connector collar 111 threadedly attached to threads 110a and arranged to be interconnected into a standard tubing string.
  • Tubing receiver 110 is threaded into upper head 112 which also receives in threaded engagement a tubular elongated secondary tubing string receiver 113.
  • Head 112 is primarily a cylindrical member having dual bore passages passing therethrough oriented substantially parallel with the central longitudinal axis of the cylindrical member. The upper portions of the dual bore passages have internal threads 112a for receiving tubular sections 110 and 113.
  • Tubular receiving member 113 has an enlarged chamber area 114 attached to a standard tubular section or neck 115 and containing an annular inwardly projecting shoulder 116.
  • upper receiver dish 117 Threadedly attached to the upper end of member 113 at threads 113a and slidably encircling member 110 is upper receiver dish 117 which is a generally cylindrical section having a concave upper face 121 and dual bore passages 119 and 120 to receive member 110 and the secondary tubing string collet sleeve 118.
  • Collet sleeve 118 is a tubular member having an annular shoulder 123 sized to abut shoulder 116 and be retained thereby.
  • Longitudinal slots 122 are formed through the wall to give the remainder of the sleeve flexibility and allow shoulder 123 to flex inward and traverse shoulder 116.
  • a cylindrical, tubular seal carrier collar 124 is threadedly attached to sleeve 118 and contains seal elements 125 encircled thereon to seal against bore 114 of receiver 113.
  • a standard length of tubing 126 can be threadedly attached into collar 124.
  • Upper head 112 contains inner annular abutment ridges 112b in bore passages 130 and 131 to receive in snug fitting relationship the primary and secondary mandrels 107 and 108 which mandrels are elongated cylindrical tubular members extending substantially through the entire tool.
  • Each mandrel 107 and 108 has an annular exterior shear shoulder 107a and 108a for abutment with and selective shear means for shear screws 127 which project through the wall of head 112 and into the shear chamber 128 formed between head 112, shoulders 107a and 108a and mandrels 107 and 108.
  • a cylindrical abutment shell 129 is secured to head 112 by threaded bolts 132 passing through the head and threadedly engaging shell 129 as shown in the discontinuous cross-sectional view of FIG. 9.
  • This cross section must be shown in broken or discontinuous sec-1 tion in order to show the bolts since a normal cross section at line -10 of FIG. 9 would not clearly show them.
  • FIG. 11d shows a cross-sectional axial view of one of the key-retaining sleeves 133 and 134
  • FIG. 11c shows a crosssectional axial view of a sleeve.
  • Shell 129 also consists of a thick wall area and a thin wall area as shown in FIGS. 11 and 12.
  • the narrowed walls of shell 129 and of sleeves 133 and 134 are to allow side by side placement of the two mandrels 107 and 108 within the dimensions of the sleeves and the shell.
  • Shell 129 has at its lower end an inwardly projecting flange 129a through which pass locking collet sleeves 135 and packer assembly bolts 136 concentrically located within sleeves 135.
  • Sleeves 135 each have a small spring lip 1350 on the outer edge of the upper end for engaging flange 129a and an outer abutment flange 135b at the lower end for abutment and retention of upper packer plate 137 to head 112. This prevents head 112 from floating upward on bolts 136 away from plate 137 and prematurely shearing of screws 127 while going in the hole with the tool.
  • Key-retaining sleeves 133 and 134 are arranged so that slots in the sleeves are located directly over parallel, exterior circumferential ridges 138 and 139 on mandrels 107 and 108. Retaining keys 140 are snugly fitted within the slots and abut the mandrels between the ridges as shown in FIG. 9. This arrangement temporarily locks the mandrels to the upper head assembly 103 by means of keys 140, ridges 138 and 139 and sleeves 133 and 134 and allows the operator to pick up on the string and reciprocate it to dislodge sediment or other material which may be binding between the tool string and the casing while going in the hole. This protects shear pins 127 from premature shearing.
  • FIGS. 11a 11c give views of the sleeves and keys disassembled from the apparatus for a'better understanding of their structure.
  • the resilient packer assembly is located slidably about the mandrels 107 and 108 below upper packer plate 137 and consists of resilient packer elements 141, rigid spacer plates 142 and lower packer plate 143.
  • a dual wedge-cone head 144 is abutted against lower plate 143 in encircling relationship about mandrels 107 and 108 and wedge anchors 145.
  • Anchors are wedge shaped inserts having a plurality of angled gripping teeth on their inner surface contacting the outer wall of the mandrels.
  • FIGS. 16a and 16b more detailed view of the dual wedge-cone head 144 is shown in FIGS. 16a and 16b.
  • Guide pins 146 project through head 144 and into slots 145b formed in the outer portion of wedge inserts 145 to prevent the anchors from rotating around on the mandrel and getting out of optimum gripping position which is with each anchor diametrically opposed to another anchor about the mandrel.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Piles And Underground Anchors (AREA)
  • Catching Or Destruction (AREA)
  • Pressure Welding/Diffusion-Bonding (AREA)
US00412386A 1973-11-02 1973-11-02 Dual hydraulically actuated oil well packer Expired - Lifetime US3851705A (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
US00412386A US3851705A (en) 1973-11-02 1973-11-02 Dual hydraulically actuated oil well packer
CA208,792A CA1002449A (en) 1973-11-02 1974-09-09 Dual string hydraulically actuated oil well packer
US504010A US3915261A (en) 1973-11-02 1974-09-09 Shearable ratchet mechanism
GB40884/74A GB1483072A (en) 1973-11-02 1974-09-19 Dual hydraulically actuated oil well packer
GB7923/77A GB1483073A (en) 1973-11-02 1974-09-19 Well packers
DE2452433A DE2452433C3 (de) 1973-11-02 1974-11-01 Hydraulisch betätigter Bohrlochpacker für Zwillingsrohrgestänge

Applications Claiming Priority (1)

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US00412386A US3851705A (en) 1973-11-02 1973-11-02 Dual hydraulically actuated oil well packer

Publications (1)

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US3851705A true US3851705A (en) 1974-12-03

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US00412386A Expired - Lifetime US3851705A (en) 1973-11-02 1973-11-02 Dual hydraulically actuated oil well packer

Country Status (4)

Country Link
US (1) US3851705A (de)
CA (1) CA1002449A (de)
DE (1) DE2452433C3 (de)
GB (2) GB1483073A (de)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4852649A (en) * 1988-09-20 1989-08-01 Otis Engineering Corporation Packer seal means and method
US5096209A (en) * 1990-09-24 1992-03-17 Otis Engineering Corporation Seal elements for multiple well packers
US6202747B1 (en) * 1998-09-02 2001-03-20 Schlumberger Technology Corporation Hydraulic well packer and method
CN103630349A (zh) * 2013-12-09 2014-03-12 武汉海王机电工程技术公司 压缩式封隔器试验装置

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5425418A (en) * 1994-04-26 1995-06-20 Baker Hughes Incorporated Multiple-completion packer and locking element therefor
CN107558946B (zh) * 2017-10-27 2019-07-23 河北恒安泰油管有限公司 一种封隔器
CN110821440B (zh) * 2019-11-29 2024-04-16 长江大学 一种封隔器

Citations (9)

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Publication number Priority date Publication date Assignee Title
US2159640A (en) * 1938-08-29 1939-05-23 Carl E Strom Deep well cementing device
US3224508A (en) * 1962-12-26 1965-12-21 Cicero C Brown Hydraulic packer with safety joint release
US3288218A (en) * 1963-10-03 1966-11-29 Otis Eng Co Well tools and apparatus
US3370651A (en) * 1966-04-01 1968-02-27 Joe R. Brown Well packer
US3381752A (en) * 1965-12-06 1968-05-07 Otis Eng Co Well tools
US3414058A (en) * 1965-05-18 1968-12-03 Baker Oil Tools Inc Well bore packer
US3714984A (en) * 1971-12-20 1973-02-06 Dresser Ind Well tools and gripping members therefor
US3739849A (en) * 1971-02-01 1973-06-19 Dresser Ind Gripping member for well tool
US3804164A (en) * 1973-04-09 1974-04-16 Dresser Ind Well packer apparatus having improved hydraulically-actuated anchor assembly

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2159640A (en) * 1938-08-29 1939-05-23 Carl E Strom Deep well cementing device
US3224508A (en) * 1962-12-26 1965-12-21 Cicero C Brown Hydraulic packer with safety joint release
US3288218A (en) * 1963-10-03 1966-11-29 Otis Eng Co Well tools and apparatus
US3414058A (en) * 1965-05-18 1968-12-03 Baker Oil Tools Inc Well bore packer
US3381752A (en) * 1965-12-06 1968-05-07 Otis Eng Co Well tools
US3370651A (en) * 1966-04-01 1968-02-27 Joe R. Brown Well packer
US3739849A (en) * 1971-02-01 1973-06-19 Dresser Ind Gripping member for well tool
US3714984A (en) * 1971-12-20 1973-02-06 Dresser Ind Well tools and gripping members therefor
US3804164A (en) * 1973-04-09 1974-04-16 Dresser Ind Well packer apparatus having improved hydraulically-actuated anchor assembly

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4852649A (en) * 1988-09-20 1989-08-01 Otis Engineering Corporation Packer seal means and method
US5096209A (en) * 1990-09-24 1992-03-17 Otis Engineering Corporation Seal elements for multiple well packers
US6202747B1 (en) * 1998-09-02 2001-03-20 Schlumberger Technology Corporation Hydraulic well packer and method
CN103630349A (zh) * 2013-12-09 2014-03-12 武汉海王机电工程技术公司 压缩式封隔器试验装置
CN103630349B (zh) * 2013-12-09 2016-08-17 武汉海王机电工程技术公司 压缩式封隔器试验装置

Also Published As

Publication number Publication date
DE2452433A1 (de) 1975-05-07
DE2452433B2 (de) 1979-06-21
GB1483072A (en) 1977-08-17
CA1002449A (en) 1976-12-28
GB1483073A (en) 1977-08-17
DE2452433C3 (de) 1980-02-28

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