Abstract: A liner hanger assembly seals with casing 22 and supports a liner 90 within a well. The tubular liner hanger body 50 and a tubular expander 40 may be positioned downhole at a desired depth on a running tool. An actuator assembly 12, 24 may forcibly move the tubular expander 40 into the liner hanger body 50, expanding the liner hanger body to seal and secure the hanger body to the casing string 22. The running tool may be released from the set liner hanger by an axially movable collet mechanism, such as ratchet ring 92 and a catch mechanism, such as threads 94. The running string thus need not be rotated to release from the set liner hanger.

Abstract: The liner hanger assembly seals with casing 8 and supports a liner 98 within a well. The tubular liner hanger 48 and a tubular expander 40 may be position downhole on a running tool at a desired depth along the casing string 8. An actuator assembly 6 may forcably move the tubular expander 40 into the tubular hanger, expanding the liner hanger to seal and secure the hanger against the casing string 8. After the running tool has been removed, a seal nipple may be sealed to the sealing sleeve of the tubular expander. A selectively releasable clutch 73 is provided for allowing rotation of the liner to rotate the liner with the running tool, and thereafter to disengage and release the running tool from the set liner hanger.

Abstract: An expansion-set fluid production assembly transfers well fluids from a casing string 12 to a production tubing string 112. A tubular anchor 72 and tubular expander 70 may be positioned downhole on a running tool at a desired depth along the casing string 12. An actuator assembly 10 may forcibly move the tubular expander 70 into the tubular anchor 72, expanding the tubular anchor 72 to seal and secure the tubular anchor 72 against the casing string 12. The running tool actuator assembly 10 may be removed, leaving the expanded tubular anchor 72 and tubular expander 70 downhole. A seal nipple 122 may be sealed with the tubular expander 70 and to the production tubing string 112. Fluids may then be recovered from the wellbore through the casing string 12, through the fluid production assembly, and into the production tubing string 112.

Abstract: A whipstock assembly includes a tubular anchor 36 which is expanded into engagement with the casing string 8, and a tubular expander 24 which is forcibly moved into the tubular anchor to expand the tubular anchor downhole into secure engagement with the casing string. The tubular anchor and tubular expander remain downhole. An orientation sleeve 18 at the upper end of the expander 24 includes an orientation surface 20. A whipstock 70 engages the sleeve 18 to orient the whipstock face for diverting a tool into a hole in the side of the casing string. Once the whipstock 70 is removed from the well, the orientation sleeve may receive a sealing nipple 130 at the lower end of a production tubing string.

Abstract: A subsea riser disconnect assembly 10 may be actuated from a drilling rig DR by axial movement of an upper riser 35 relative to a lower riser 28, for disconnecting the upper riser 35 from the lower riser 28. A subsea riser valve assembly 20 may be actuated from the drilling rig DR by axial movement of the upper riser 35 relative to the lower riser 28, for sealing an interior portion of the lower riser 28 and well bore WB below the subsea riser valve assembly 20. A drill pipe disconnect 30 may be actuated from a drilling rig DR, either onshore or offshore, for disconnecting an upper portion of drill pipe 236 from a lower portion of drill pipe 240. The drill pipe disconnect 30 may be actuatable by hydraulic and/or mechanical forces applied to the drill pipe disconnect 30 from the drilling rig DR. The drill pipe disconnect 30 may be compatible for use with or without the subsea riser disconnect assembly 10 and/or the subsea riser valve assembly 20.

Abstract: A whipstock assembly includes a whipstock body 8 having a whipstock center of gravity offset radially from the central axis of the whipstock body, a counterweight to releasably secured to the whipstock body, with a counterweight having an offset counterweight center of gravity, an orientation device 5, and a neutralizer 11. The neutralizer causes the combined whipstock/neutralizer center of gravity to be substantially closer to the central axis of the whipstock body compared to the whipstock center of gravity. An attaching mechanism 6, 12 allows the neutralizer to be returned to the surface after the whipstock body is set in the well.

Abstract: A system for forming a patch in a well at a location along a tubular string which has lost sealing integrity includes a central patch body 60, an upper expander body 52 carrying an upper seal 50 or 56, and a lower expander body 98 carrying a lower seal 102, 104. The running tool includes an inner mandrel 14 axially moveable relative to the central patch body, and one or more pistons 20, 30, 20A axially moveable relative to the inner mandrel in response to fluid pressure within the running tool. Top expander 48 is axially moveable downward relative to the upper expander body in response to movement of the one or more pistons. The expander sleeves may remain downhole to radially support the downhole tubular.

Abstract: A system for forming a patch in a well at a location along a tubular string which has lost sealing integrity includes a central patch body 60, an upper expander body 52 carrying an upper seal 50 or 56, and a lower expander body 98 carrying a lower seal 102, 104. The running tool includes an inner mandrel 14 axially moveable relative to the central patch body, and one or more pistons 20, 30, 20A axially moveable relative to the inner mandrel in response to fluid pressure within the running tool. Top expander 48 is axially moveable downward relative to the upper expander body in response to movement of the one or more pistons, and a bottom expander 120 is axially moveable upward relative to a lower expander body. After the upper expander body and a lower expander body have been moved radially outward into sealing engagement with a downhole tubular string, the running tool is retrieved to the surface.

Abstract: A gripping tool 10 may be positioned in a well on a running string RS to at least temporarily secure the gripping tool to a borehole wall. The gripping tool includes a drag member 72, a plurality of slips 40, 48, and a cone member 30, 46. A slip setting mechanism 88 is provided for securing the slips in the radially inward position when the slip setting mechanism is run-in the well. At least one ramp moves the slip setting mechanism to a released position upon rotation of the running string in a first direction. A ratchet member rotationally releases the running string from the slip setting mechanism when the running string is rotated in an opposing direction. The tool may be set, released by pickup and returned to the run-in position, then reset without returning the tool to the surface.

Abstract: A system for forming a patch in a well at a location along a tubular string which has lost sealing integrity includes a central patch body 60, an upper expander body 52 carrying an upper seal 50 or 56, and a lower expander body 98 carrying a lower seal 102, 104. The running tool includes an inner mandrel 14 axially moveable relative to the central patch body, and one or more pistons 20, 30, 20A axially moveable relative to the inner mandrel in response to fluid pressure within the running tool. Top expander 48 is axially moveable downward relative to the upper expander body in response to movement of the one or more pistons, and a bottom expander 120 is axially moveable upward relative to a lower expander body. After the upper expander body and a lower expander body have been moved radially outward into sealing engagement with a downhole tubular string, the running tool is retrieved to the surface.

Abstract: A subsea riser disconnect assembly 10 may be actuated from a drilling rig DR by axial movement of an upper riser 35 relative to a lower riser 28, for disconnecting the upper riser 35 from the lower riser 28. A subsea riser valve assembly 20 may be actuated from the drilling rig DR by axial movement of the upper riser 35 relative to the lower riser 28, for sealing an interior portion of the lower riser 28 and well bore WB below the subsea riser valve assembly 20. A drill pipe disconnect 30 may be actuated from a drilling rig DR, either onshore or offshore, for disconnecting an upper portion of drill pipe 236 from a lower portion of drill pipe 240. The drill pipe disconnect 30 may be actuatable by hydraulic and/or mechanical forces applied to the drill pipe disconnect 30 from the drilling rig DR. The drill pipe disconnect 30 may be compatible for use with or without the subsea riser disconnect assembly 10 and/or the subsea riser valve assembly 20.

Abstract: A whipstock assembly 10, 110 for setting within a casing C includes a whipstock body 12, 112 having a whipstock diversion face 24, 124 for diverting a tool with respect to the casing. At least one wedge member 32, 132, 133 is moveable relative to the whipstock body and supports one or more wedge slips, 34, 36, 134, 136 thereon for anchored engagement with the casing. The wedge member has a whipstock body engaging surface 98 for sliding engagement with a lower wedge engaging surface 96 on the whipstock body. An elongate rod or other actuation member 40 moves the at least one wedge member from the run in position to the set position. According to the method of the invention, the whipstock and anchor assembly may be run into the well through a tubing string then set in the casing. The whipstock assembly may be of the type which is retrievable to the surface after having been set in the casing.

Abstract: A whipstock assembly 10 for setting within a casing C on an anchor A diverts a cutting mill M to cut a window in the casing. The whipstock assembly is passed through a restriction positioned above the location where the whipstock assembly is set, is lowered past the restriction in a run in position, and is set within the casing in a set position. The whipstock assembly includes an upper whipstock body 20 having a ramp surface 22, 26, a middle lower whipstock body 60 having a concave guiding face 72, and a lower whipstock body 110 having a concave whipstock diversion face 112. A lower hinge member 118 is provided for positioning the concave whipstock diversion face for diverting the cutting mill, and at least one whipstock positioning member 80, 100 engages the casing when in the set position for positioning the middle whipstock body guiding face.

Abstract: An assembly for drilling multiple laterals (26) from a borehole and into a formation includes a whipstock assembly having a radially movable lug (82). An elongate tubular secured within the borehole has one or more non-ferrous portions (30) and a ferrous portion (52) adjacent and below a respective non-ferrous portion. A locator (54) is fixed within each ferrous portion at a desired axial spacing relative to the non-ferrous portion. According to the method of the invention, the whipstock assembly is lowered below the locator (54) and pulled upwardly to rotate the whipstock assembly to a selected azimuth within the tubular. The lug (82) on the whipstock assembly fits within the locator to axially position the whipstock face (97) within the non-ferrous portion of the tubular. A drill bit (96) engages the whipstock face and drills a window through the non-ferrous portion of the tubular and then into the formation.

Abstract: Mechanical thru-tubing centralizers 12, 14 positioned along a work string WS centralize a tool such as an abrasive cutter AC within a large diameter casing C after passing through a small diameter tubing T. The centralizer 12 includes a body 60 having a throughbore 62 for transmitting fluid through the centralizer to the abrasive cutter AC. The centralizer 12 also includes arm support sleeves 44, 46 each movable axially between a set position and a retracted position in response to the biasing forces of coil springs 40, 42. The springs 40, 42 bias the arm support sleeves, such that a plurality of circumferentially spaced upper arms 48 and a corresponding plurality of circumferentially spaced lower arms 50 are each inclined with respect to the centralizer body 60. Pads 52 pivotally connected to the upper and lower arms are substantially moved radially outward with respect to the centralizer body and thus engage the inner diameter of the casing string C to maintain the centralizer in a set position.

Abstract: A thru tubing whipstock assembly 10 may be set within a casing string CS after passing through the lower end of a smaller diameter tubing string TS. Once set within the casing string CS, the whipstock face 18 on whipstock body 12 may divert a rotatable bit B for cutting a window in the casing string CS. The whipstock assembly 10 includes an anchor A below the whipstock body 12 for securing the set whipstock assembly within the casing string. A hinge assembly 14 below the whipstock body 12 may be pivoted from a run-in position for passing through the tubing string to a set position for positioning the whipstock face 18 for engagement with the bit B. A wedge assembly 38 is provided at the upper end of whipstock body 12 and is also movable from a run-in position to a set position.

Abstract: A fluid jetting arrangement for fluid jetting a surface including a body (B) to receive jetting nozzle extenders (NE) which in one embodiment comprise a plurality of jetting nozzle extenders having voids there between providing surfaces for controlling the relative extension of the jetting nozzle extenders for moving a jetting nozzle extender having a jetting nozzle (16) with orifice (O) therein to position the jetting nozzle with the orifice (O) to fluid jet a surface and another embodiment wherein the jetting nozzle extender (NE) is integrally formed and positioned in the body (B) to fluid jet a surface.

Abstract: A thru-tubing centralizer 10, 102 positioned along a tubular T after passing through a small diameter tubing string TS centralizes the tubular within a large diameter casing string CS. The centralizer includes a body 12, 112 having a throughbore 14 for transmitting fluid through the centralizer, such that a drill motor M and rotatable bit B may be suspended from the tubular T below the centralizer. The centralizer includes a piston 20, 136 and arm support sleeve 30, 130 each movable axially between a set position and a released position in response to increased fluid pressure in the throughbore of the centralizer body. The compression spring 40, 156 biases an arm support sleeve to a set position, such that a plurality of circumferentially spaced upper arms 50, 116 and a corresponding plurality of circumferentially spaced lower arms 60, 126 are each inclined with respect to the centralizer body to maintain the centralizer in a set position for engaging the casing string.

Abstract: A bridge plug assembly 10 contracts radially inwardly to pass through tubing string T and then expands radially outwardly in response to axially compressive forces to set within a casing string C. Upper and lower independently moveable slips 52 and 54 of the anchor mechanism 12 engage casing C. The packoff mechanism 14 includes a plurality of upper sealing members 160, 162, 164 and a plurality of lower sealing members 166, 168, 170 having varying elasticity such that at least some of the sealing members overlap other sealing members when the bridge plug 10 is compression set in the casing C. The bridge plug assembly 10 is retained in a contracted position for passing downwardly through tubing T, then expanded for sealing engagement with casing C. The bridge plug 10 may be run-in with a setting tool ST and may be subsequently released by a releasing tool RT to drop within the well.

Abstract: Retrievable window cutting apparatus and method include a whipstock assembly 160 and anchor assembly 10. Whipstock assembly 160 and anchor assembly 10 contract radially inwardly to pass through tubing string T and then expand radially outwardly to operate in casing C. Upper and lower independently moveable slips 24 and 26 engage casing C. Whipstock assembly 160 includes hinge assembly 170 that can be set for operation with a milling assembly 270. Cooperation between shear members in setting tool WSS, working string adaptor 180, hinge assembly 170, and anchor assembly 10 provide for keeping whipstock assembly 160 and anchor assembly 10 in a contracted position for passing downwardly through tubing T, expansion in casing C, and subsequent retrieval through tubing T.