ОПОРНАЯ ПЛИТА ДЛЯ БУРЕНИЯ И ОБУСТРОЙСТВА СКВАЖИН (ВАРИАНТЫ) И СПОСОБ ЕЕ ИСПОЛЬЗОВАНИЯ

Изобретение относится к области бурения скважин, а именно к деформируемой опорной плите для множества скважин и к способу бурения множества подземных скважин с помощью этой опорной плиты, размещаемой внутри ствола подземной скважины и расширяющейся при бурении скважин. Сущность изобретения заключается в том, что опорная плита размещается в скважине, расширяется и через упомянутую опорную плиту бурится, по меньшей мере, один подземный ствол скважины. По меньшей мере, одна часть опорной плиты деформирована и может быть симметричной или асимметричной в деформированном или в расширенном виде. Изобретение позволяет обеспечить бурение и обустройство множества скважин, из ствола общепринятого размера, при этом увеличивается производительность добычи углеводородов и повышается надежность гидравлического уплотнения у упомянутой опорной плиты. 3 с. и 14 з.п.ф-лы, 28 ил.

АППАРАТ И СПОСОБ УПРАВЛЕНИЯ СКВАЖИННЫМ УСТРОЙСТВОМ

Группа изобретений относится к горному делу и может быть применена для управления скважинным устройством. Аппарат для управления скважинным устройством в скважине содержит корпус с управляющим пазом и перемещающимся в пазу пальцем. У паза есть первый неактивный контур, в котором палец может циклически перемещаться между различными холостыми конфигурациями, и второй активный контур, в котором палец может перемещаться между различными конфигурациями, соответствующими активному и неактивному состояниям скважинного устройства. Палец может переключаться между первым и вторым контурами, а также циклически перемещаться между различными конфигурациями в рамках одного контура без перехода в другой контур. Паз может располагаться на поршне, и осевое движение поршня в стволе может обеспечивать перемещение пальца и паза относительно друг друга. Технический результат заключается в повышении эффективности управления скважинным устройством. 2 н. и 16 з.п. ф-лы, 37 ил.

ДВУНАПРАВЛЕННЫЙ ИНСТРУМЕНТ С БАЙОНЕТНЫМ ПАЗОМ

Предложен многопозиционный инструмент для использования на забойном конце транспортировочной колонны для выполнения работ в обсадной колонне. Этот инструмент содержит оправку, соединенную с транспортировочной колонной; корпус механизма приведения в действие, выполненный с возможностью скольжения в осевом направлении вдоль оправки между устьевым положением, по меньшей мере одним промежуточным положением и забойным положением; устройство с устьевой стороны, выполненное с возможностью функционирования между положением приведения в действие, в котором корпус механизма приведения в действие находится в устьевом положении, и нерабочим положением; и устройство с забойной стороны, выполненное с возможностью функционирования между положением приведения в действие, в котором корпус механизма приведения в действие находится в забойном положении, и нерабочим положением. Как устройство как с устьевой, так и устройство с забойной стороны находятся в их нерабочих положениях, когда корпус механизма приведения ...

УПРАВЛЯЕМЫЙ РОТОРНЫЙ ИНСТРУМЕНТ

... 1. Управляемый роторный инструмент, выполненный с возможностью монтирования в забойном буровом устройстве для корректировки направления бурения устройства, при этом управляемый роторный инструмент содержит: ! трубчатый внешний корпус; ! по меньшей мере, один управляемый толкатель, подвижно закрепленный на корпусе для перемещения между выдвинутым положением, в котором управляемый толкатель касается стенки скважины, образованной буровым устройством, и убранным положением, в котором управляемый толкатель не касается стенки скважины; ! трубчатый вал, смонтированный внутри корпуса и выполненный с возможностью подсоединения на первом и втором своих концах к буровой колонне для передачи вращающего усилия к буровому долоту, при этом вал образует канал для прохождения бурового раствора к буровому долоту; ! камеру давления, образованную между валом и корпусом, и соединяющуюся, по меньшей мере, с одним упомянутым управляемым толкателем для осуществления перемещения управляемого толкателя из убранного ...

UNTERSUCHUNGSVORRICHTUNG ZUR MEHRFACHAUSNUTZUNG.

WERKZEUG ZUM ABDICHTEN EINES STEIGROHRES.

UMLAUFVENTIL IM BOHRLOCH UND VERFAHREN FUER SEINE BEDIENUNG.

Mehrzweck-Bohrlochgeraet

Modular hydraulic operator for a subterranean tool

Tool retainer

Hydraulic control of drill string tools

METHOD AND APPARATUS FOR COMPLETION OF A WELL

ANCHORING TUBING STRINGS IN WELLBORES.

A locking mechanism for anchoring a tubing string to a hollow bore sump packer located at a position in a subterranean well. The locking mechanism is attachable to the end of a tubing string and incorporates radially shiftable locking members which are engagable with an internal, downwardly facing shoulder defined within the hollow bore of the sum packer. The radially shiftable locking elements are moved from a retracted to a locking position by reciprocating movements of a mandrel carried by the tubing string. A supporting surface on the mandrel controls the position of the radially shiftable locking elements. The position of the supporting surface relative to the radially shiftable locking elements is controlled by a J-pin secured to the sleeve carrying the radially shiftable locking elements and a cooperating J-slot carried by the mandrel. The configuration of the J-slot requires that the mandrel be shifted downwardly and then upwardly to engage the locking elements with the packer shoulder ...

Well abandonment system

A remedial bottom hole assembly for casing retrieval comprises a spear and an inflatable packer utilized in combination with a pipe cutter. With such an assembly, after the spear is set and the casing is cut, the packer can be inflated to determine if circulation can be established without the removal of the spear and pipe cutter. ...

Flow control apparatus for use in a wellbore

An apparatus and method of controlling the flow of hydrocarbons into and/or out of a string of tubing disposed in a wellbore. In one aspect, the apparatus comprises a tubular member 122 having at least one aperture 124 formed therein and a fixed ring 127 and a rotatable ring 126 disposed radially outward of the tubing member 122. The rings have voids formed on their outer surfaces and the rotatable ring 126 is movable to align the voids of the fixed and rotatable ring to create a passage 129 along the outer surface of the fixed ring 127 and the rotatable ring 126. A chamber 125 is provided in communication with the passage 129 and the aperture 124 of the tubular member 122. Also disclosed are a method and system for controlling the flow in wellbore operations, comprising a plurality of flow control apparatuses coupled to a string of tubing.

SEALED JOINTS BETWEEN TELESCOPIC PIPE MEMBERS

BEARING ASSEMBLY FOR TELESCOPIC PIPE MEMBERS

A tubing string (20, Fig. 1) is adapted to be lowered into the bore in the upper end of a well conduit (22) and has one or more rings (25) retained within annular grooves 26 by means of retainer rings (30). A bearing assembly is provided on the string comprising at least one ring 55 of a nonelastic bearing material to provide a bearing surface engaging the interior surface of the well conduit 53. The ring 55 is circumferentially split to enable it to be moved into the groove 54 and is held in place by a compressible ring 57. ...

APPARATUS FOR CONTROLLING THE OPERATION OF A DOWNHOLE TOOL

Cam systems

Method and apparatus for positioning and repositioning a plurality of service tools downhole without rotation

Method and apparatus for selective injection or flow control with through-tubing operation capacity

A downhole flow control device is provided for remotely controlling fluid flow of production or injection fluids, and may offer the capacity to pass wireline tools therethrough. In a broad aspect, the device may include: a body member having a first bore extending from a first end of the body member and through an extension member disposed within the body member, a second bore extending from a second end of the body member and into an annular space disposed about the extension member, a first valve seat disposed within the first bore, and at least one flow port in the extension member establishing fluid communication between the annular space and the first bore; and a first sleeve member remotely shiftable within the first bore, and having a second valve seat adapted for cooperable sealing engagement with the first valve seat to regulate fluid flow through the at least one flow port. The device may also include: a closure member disposed for movement between an open and a closed position ...

Choke valve with rotatable sleeve

A choke valve 100 is disclosed for controlling the flow of fluid through a production tubing (10, fig 1A). The valve includes a housing 20 having axially aligned apertures 25 and a ported sleeve 30 disposed within the housing. The ported sleeve has rows of fluid ports 35. Each row of ports has at least one port in selective fluid communication with a respective aperture. In the full open position, each aperture is in fluid communication with a port from each row. To choke the flow, the ported sleeve is rotated relative to the housing to reduce the number of ports in fluid communication with the housing. To close the valve, axial force is applied to move the ported sleeve axially relative to the housing. An actuator for rotating a sleeve disposed within a housing is also disclosed.

An apparatus for diverting fluid flow out of a work string

A downhole apparatus for diverting fluid flow out of a work string comprising a top sub 10 connected to a piston housing 20 and an upper piston 70, a middle piston 80 and a lower piston 90 are positioned within the housing as is a locating sleeve 110 which has a j-track 115. A locating pin 45 connected to the piston housing is located within the j-track. A spring housing 40 containing spring 55 is connected to a lower end of the piston housing. A ported housing 50, having a plurality of ports 130 is connected to the lower end of the spring housing and a lower sub 60 is connected to a lower end of the ported housing. A flow tube 100 having a restriction 105 is located within the central bores of the ported, spring and piston housings and is connected to the locating sleeve. Fluid flow through the restriction creates an increase in fluid pressure causing the movement of the pistons. The pistons move the flow tube between various locations within the apparatus. In one location, the flow tube ...

Latchable carrier assembly for pipe conveyed well logging

A circulating sub apparatus and method

Downhole apparatus

CASING HANGER RUNNING TOOL USING ANNULUS PRESSURE

Downhole tool

Improved multi-cycle downhole apparatus

Multi-cycle downhole apparatus

Downhole apparatus (302), particularly, multi-cycle circulating subs used during downhole drilling operations, comprises a piston (242) slidably mounted in a body between positions in which at least one aperture in the body is opened and closed. Movement of the piston (242) is controlled by a pin (86), secured to one of the body and a control member, and a control groove (52) formed in the other of the body and control member for receiving a portion of the pin. An arrangement of elements (232,276) respectively connected to the control member and body is such as to normally resist axial movement of the control member from a first axial position to a second axial position. A spring (44) is located in a chamber for biasing the piston (242). The chamber is vented by an opening (369) in the body. This opening reduces the risk of the piston bouncing.

Internal riser rotating control head

Internal riser rotating control head

A system for forming a subsea borehole is provided, whereby the borehole is formed by utilising a rotatable pipe P, and a fluid. The system comprises a subsea housing 14 that is positioned above the borehole. A bearing assembly 28 is mounted with the housing, the bearing assembly featuring an inner 36 and outer 38 member, with the inner member rotatable relative to the outer member, and with a passage within it allowing the rotatable pipe to extend through the bearing assembly. A seal is also provided to seal the bearing with the rotatable pipe. Finally, a holding member 24 is employed to locate the entire bearing assembly within the subsea housing. Numerous other embodiments are disclosed, some utilising a feature whereby the fluid pressure in the system can be increased to control borehole pressure.

Downhole tubular splitter assembly and method

A splitter assembly (10) is positioned downhole within a conductor (50) for separating two or more tubular strings placed within the conductor. A splitter housing may include a first bore (26) and a second bore (28) for separating a first well from a second well, and a plug (24) positioned in one of the bores including a top face (25) sloping downwardly toward the other bore. One or more guide plates (18) secured to the splitter housing and positioned above the plug guide a bit or other tool toward one of the first bore and the second bore. The splitter housing (10) may be positioned along the conductor (50) after the conductor is jetted in place. According to the method, the plug in one of the bores is retrieved after a casing is run in one well, so that the second bit and the second casing will pass through the bore which previously included the plug.

Downhole tubular splitter assembly and method

Apparatus for changing wellbore fluid temperature

Surface control bent sub for directional drilling of petroleum wells

Directional drilling apparatus for incorporation in a drill string, wherein a lower apparatus section is angularly deviated from vertical by cam action and wherein rotational displacement of the angularly deviated apparatus section is overcome by additional cam action, the apparatus being operated by successive increases and decreases of internal drill string pressure.

Downhole tool for debris removal

Hydraulic control system for downhole tools

A hydraulic control system and associated methods provides selective control of operation of multiple well tool assemblies. In a described embodiment, a hydraulic control system includes multiple control modules, each of which has a member that is displaceable to multiple predetermined positions to thereby select a corresponding one of multiple well tool assemblies for operation thereof. When the member of a certain control module is in a selected position, an actuator of a corresponding one of the well tool assemblies is placed in fluid communication with a flowpath connected to the control module. The members of the multiple control modules are displaced simultaneously in response to pressure on a line connected to each of the control modules.

Downhole flow control device with ratchet mechanism

The present invention relates to apparatus utilised in conjunction with subterranean wells. The invention provides a flow control device (102), such as a variable choke, comprising a ratchet mechanism (106) operable in response to pressure applied thereto; and a member (104) incrementally displaceable by the ratchet mechanism (106) such as a J-slot, displacement of the member (104) progressively varying a flow areas through the flow control device.

Downhole actuating method and apparatus

The remotely energized actuator device 10 facilitates storage of energy needed to actuate a downhole tool after the device is placed downhole so surface exposure to potential safety hazards is reduced. A gas chamber 16 charged with a gas (eg nitrogen) at the surface contains an annular piston 18 which is acted upon by hydrostatic pressure as it is lowered into the well. Pressure in the chamber 16 is then increased via a tubing (not shown) until piston 18 locks into position via ratchet 22 mating surfaces 24,28. This trapped pressure may be used for actuating a tool or an isolation or safety valve. Alternatively to the gas chamber, a mechanical spring may be used. The device may be used in combination with a pin and J-slot mechanism, or a shear mechanism and/or rupture disk for safety.

Cyclic check valve for coiled tubing

Circulation sub with indexing mechanism

Tool with multi-size segmented ring seat

Formation treatment system

Controller for downhole tool

SURFACE CONTROLLED BLADE STABILIZER

Downhole tool actuation system having indexing mechanism and method

A downhole tool actuation system including: a tubing having a longitudinal axis and a main flowbore supportive of tubing pressure; an indexing mechanism in fluidic communication with the main flowbore, the indexing mechanism configured to count N number of tubing pressure cycles; a port isolation device movable between a blocking condition and an actuation condition, the port isolation device in the blocking condition for N-1 cycles of the indexing mechanism, and movable to the actuation condition at the Nth cycle of the indexing mechanism; and, a chamber sealed from the main flowbore in the blocking condition of the port isolation device, the chamber exposed to the tubing pressure in the actuation condition of the port isolation device. The downhole tool actuation system is configured to actuate a downhole tool upon exposure of the chamber to tubing pressure.

Sealing device having high differential pressure opening capability

A sealing device for use in a flow control apparatus 1 is provided. The sealing device comprises a static seal 10 and a protective seal 11 or fluid restriction. The protective seal 11 is formed between two members 12, 13 formed from resilient materials being substantially resistant to wear or failure when exposed to large pressure differentials and associated jetting action. The static seal 10 is formed using a sealing element that comprises a material that is at least partially deformable, such as an elastomer or the like. The protective seal 11 is engaged prior to engaging or disengaging the static seal 10 in order to prevent damage to the deformable material of the static seal.

Downhole valve

mechanically coupling a bearing assembly to a rotating control device

PARKING MANDREL

A circulating sub apparatus and method

Internal riser rotating control head

Valve operating mechanism

Improved tandem releasable bridge plug system and method for setting such tandem releasable plugs

Remote hydraulic control of downhole tools

Indexer controlled directional valve system

COMPRESSION ACTIVATED BYPASS VALVE

Positioning tool and method

A selectively activatable downhole tool

A tool comprising: a tool body having an elongate bore passing along at least a part of the length of the body; a secondary chamber within the tool body and positioned adjacent the bore; a flow port extending between the bore and the secondary chamber; a cover component positioned within the bore and moveable between at least two positions along the length of the bore; and a control arrangement connected to the cover component to control movement of the cover component within the bore, the control arrangement comprising a piston 6 which is moveable with respect to the tool body, and a guide component which is positioned adjacent the piston, one of the piston and the guide component having a track 13 formed therein, and the other of the piston and the guide component having a protruding element 32 which is received in the track, wherein: in a first position of the cover component, the cover component covers an entrance to the flow port, so that fluid flowing along the bore may not flow into ...

Hydraulic switch device.

BALL BEARING SEAT ARRANGEMENT AND PROCEDURE FOR STEERING A FLUID STREAM BY A HOLLOW BODY

ADJUSTABLE ROTATING TOOL

COMMUNICATION TOOL FOR A RELIEF VALVE UNDERNEATH THE SURFACE

PRUFGERAT ZUR UNTERSUCHUNG DER ERGIEBIGKEIT OLFUHRENDER ERD-FORMATIONEN

DEVICE AND PROCEDURE FOR BORING AND COMPLETE ANIMALS OF SEVERAL DRILLINGS

Steerable drilling tool and system

Assembly and process for drilling and completing multiple wells

INDEXING ASSEMBLY FOR A DOWNHOLE TOOL

WELL DOWN HOLE LOW PRESSURE RESPONSIVE TEST VALVE

Controller for hydraulically operated downhole tool

A hydraulic control system can be used on a downhole choke and has the feature of moving a travel stop for a sliding sleeve using discrete j-slot mechanisms for selectively moving the stop in either one of two opposed directions. The valve can be incrementally opened further with pressure cycling an opening chamber. The valve can be immediately put to the closed position with pressure on a closing chamber. After closing the valve can assume its former open position or other selected less open positions by reconfiguring the travel stop while the valve stays in closed position in order to archive a higher open percent after closing, one or more pressure cycles must be applied to the open chamber after the valve is reopened to the position it was in before it was closed.

A downhole tool and a running tool for retrievably setting a downhole tool at locations within a well bore

... -38 Abstract A rur ning tool for landing and setting a retrievable downhole tool at any 5 locati n in a well bore includes an inner rod, a running tool anchoring device mounted on the inner rod and controllably r configurable between a retracted configuration to permit movement of the tool through the well bore and a radial y extended configuration for locking engagement of the running tool with the bore wall, a running tool actuating assembly for effecting reciprocal 10 move ent of the reconfiguring the running tool anchoring device to and from the retracted and expanded configurations without interacting with any restri tions or recesses within the well bore, and a resistance device for frictio ally engaging the bore wall with sufficient gripping force so as to hold the p sition of the running tool relative to the well bore during movement of 15 the running tool actuating assembly to and from the first and second configuration upon application of the axial force. 1 of 13 - 300 21-0 -12 ...

Repeatable, compression set downhole bypass valve

A bypass valve for use in tubing string which can be repeatedly opened and closed to selectively provide bypass fluid flow between the interior of the tubing string and the annulus to assist in flowing debris. The valve uses hardened valve elements which can be opened and closed while flowing fluids under pressure through the tubing string. The valve is actuated by placing the tubing string in a sufficient weight down condition to operate the valve. A trigger is provided to prevent unintended actuation of the bypass valve during use.

Repeatable, compression set downhole bypass valve

Downhole sub with hydraulically actuable sleeve valve

A method for opening a port through the wall of a ported sub including: providing a hydraulically actuable valve to cover the port, the valve being actuable to move away from a position covering the port to thereby open the port; providing a removable pressure isolator that seals tubing pressure from accessing the valve; removing the pressure isolator from blocking access to the valve; increasing the pressure within the sub to move the valve towards a low pressure side, while the port remains closed by the valve; thereafter, reducing pressure within the sub; driving the valve to move it away from a position covering the port; and removing a portion of the pressure isolator to provide further fluid access through the ported sub.

Downhole sub with hydraulically actuable sleeve valve

A method for opening a port through the wall of a ported sub including: providing a hydraulically actuable valve to cover the port, the valve being actuable to move away from a position covering the port to thereby open the port; providing a removable pressure isolator that seals tubing pressure from accessing the valve; removing the pressure isolator from blocking access to the valve; increasing the pressure within the sub to move the valve towards a low pressure side, while the port remains closed by the valve; thereafter, reducing pressure within the sub; driving the valve to move it away from a position covering the port; and removing a portion of the pressure isolator to provide further fluid access through the ported sub.

POSITIONING AND ANCHORING A WELL TOOL

Downhole valve assembly and methods of using the same

A wellbore servicing system (100) comprising a work string (112) and a valve tool (200) defining a flowbore (52), wherein the valve tool is transitionable from a first mode to a second mode, from the second mode to a third mode, and from the third mode to a fourth mode, wherein the valve tool transitions from the first mode to the second mode upon an application of pressure to the flowbore of at least a threshold pressure, wherein the valve tool transitions from the second mode to the third mode upon a dissipation of pressure from the flowbore to not more than the threshold pressure, wherein, in the first mode, the valve tool allows fluid communication via the flowbore in a first direction and disallows fluid communication in a second direction, and wherein, in the second, and third modes, the valve tool allows fluid communication in both the first and second directions.

Method and apparatus for securing and using hydrajetting tools

A method and apparatus for securing and using hydrajetting tools within a borehole is described. The apparatus includes a housing that defines an inner bore. A flow limiting member may be disposed within the inner bore. The flow limiting member may include a first a first jet in fluid communication with the top of the housing, a first chamber positioned below and in fluid communication with the first jet, and a first cavity aligned with the first jet and in fluid communication with the chamber. A groove may be disposed on an outer surface of the housing, with an anchor assembly that is disposed around the housing and axially slidable and securable within the groove.

Wellbore servicing assemblies and methods of using the same

A wellbore servicing system comprising a casing string disposed within a wellbore, a work string at least partially disposed within the casing string and having a wellbore servicing tool incorporated therein, wherein the wellbore servicing tool is selectively transitionable between a jetting configuration and a mixing configuration, wherein the wellbore servicing tool is configured to transition between the jetting configuration and the mixing configuration via contact between the wellbore servicing tool and the casing upon movement of the work string upwardly within the casing string, upon movement of the work string downwardly within the casing string, or by combinations thereof.

Internal Riser Rotating Control Head

A system and method provides a holding member for releasably positioning a rotating control head assembly in a subsea housing. The holding member engages an internal formation in the subsea housing to resist movement of the rotating control head assembly relative to the subsea housing. The rotating control head assembly is sealed with the subsea housing when the holding member engages the internal formation. An extendible portion of the holding member assembly extrudes an elastomer between an upper portion and a lower portion of the internal housing to seal the rotating control head assembly with the subsea housing. Pressure relief mechanisms release excess pressure in the subsea housing and a pressure compensation mechanism pressurize bearings in the bearing assembly at a predetermined pressure.

Downhole tool

The invention provides a downhole initiator tool (10, 210, 410, 610) for use in initiating a downhole operation, and a method of use. The downhole initiator tool comprises a mandrel (34, 234, 434, 634), an initiator assembly (26, 226, 426, 626), and an anchor assembly (28, 228, 428, 628) mounted on the mandrel. The anchor assembly comprises a radially extendable anchor member (26, 226, 426, 626) for engaging an outer bore structure. The anchor assembly and the mandrel are axially moveable relative to each other in a first axial direction to sequentially extend the anchor member and activate the initiator assembly.

Formation evaluation tool and method for use of the same

Down hole bypass valve

COILED TUBING SET INFLATABLE PACKER, BRIDGE PLUG AND RELEASING TOOL THEREOF

Downhole valve

Adjustable stabiliser for directional drilling

OPERATING ASSEMBLY FOR A DOWNHOLE TOOL

FLUID CONTROLLED ADJUSTABLE DOWN-HOLE TOOL

An adjustable down-hole tool, for example a drill-string stabiliser (10), comprises a body (12) having a through bore (16). A mandrel (18) is rotationally fixed but axially movable in the body, the mandrel being movable by fluid pressure in the tool against the action of a first return spring (44) between a first, activated position and a second deactivated position. A sleeve (66) is between shoulders (68, 69) on the body and mandrel. Castellations (18a,b, 69a,b) are on the mandrel and facing edge or edges of the sleeve so that, when the castellations are in phase the mandrel is prevented from travelling from said first to second position and when they are out of phase they interdigitate and the mandrel is not prevented from travelling from said first to second position. A control piston (36) is slidable in the mandrel, being movable by fluid pressure in the tool against the action of a second return spring (50). The piston is axially slidable with respect to said sleeve and rotationally ...

APPARATUS FOR MAKING MULTIPLE ORIENTATION MEASUREMENTS IN A DRILL STRING

DOWNHOLE TOOL

A downhole tool (10) comprises a body (12) defining a bore. The body includes a valve arrangement (18) including flow ports (24) in the wall of the body. The ports may be opened or closed. In addition, a variable flow restriction (30) is provided in the bore (14), the degree of restriction tending to decrease as flow across the restriction increases. The variable flow restriction may be utilised to actuate the valve arrangement.

INTERNAL RISER ROTATING CONTROL HEAD

A system and method provides a holding member for releasably positioning a rotating control head assembly in a subsea housing. The holding member engages an internal formation in the subsea housing to resist movement of the rotating control head assembly relative to the subsea housing. The rotating control head assembly is sealed with the subsea housing when the holding member engages the internal formation. An extendible portion of the holding member assembly extrudes an elastomer between an upper portion and a lower portion of the internal housing to seal the rotating control head assembly with the subsea housing. Pressure relief mechanisms release excess pressure in the subsea housing and a pressure compensation mechanism pressurize bearings in the bearing assembly at a predetermined pressure.

REPEATABLE, COMPRESSION SET DOWNHOLE BYPASS VALVE

A bypass valve for use in tubing string which can be repeatedly opened and closed to selectively provide bypass fluid flow between the interior of the tubing string and the annulus to assist in flowing debris. The valve uses hardened valve elements which can be opened and closed while flowing fluids under pressure through the tubing string. The valve is actuated by placing the tubing string in a sufficient weight down condition to operate the valve. A trigger is provided to prevent unintended actuation of the bypass valve during use.

SWITCHABLE CIRCULATING TOOL

A circulating tool for use in drilling a bore hole, the tool including a plurality of pistons which, by the activation of fluid pressure, move between a first configuration in which a side port of the tool is covered by a piston and a second configuration in which two adjacent pistons separate across the port to allow fluid to jet from the port. In the first configuration, the tool has a continuous cylindrical bore to allow the passage of other tools through the tool, while a flapper valve closes the bore in the second configuration to achieve maximum jetting of fluid from the tool. A third or intermediate configuration is also described so that the tool is operable to switch multiple times between the configurations via an indexing mechanism.

TUBING RESETTABLE WELL TOOL

A tubing string resettable bridge plug is conditioned for initial wire line installation in a well utilizing an adapter within a mandrel carrying the slip assembly of the bridge plug and frangible connecting means between the sealing assembly and mandrel to place the sealing assembly in an alternate transport condition for first being set by means of a wire line device. Thereafter, the tubing string may be connected to the bridge plug downhole to release the bridge plug for resetting in a different position.

APPARATUS FOR CONTROLLING THE OPERATION OF A DOWNHOLE TOOL

A control valve is disclosed for actuating a downhole tool in response to changes in the rate of flow of drilling fluid through a pipe string. Specifically, the control valve is described in combination with downhole tools of the knuckle joint or bendable sub type used in directional drillings. The control valve produces an increase in surface pressure to indicate when the valve has been actuated.

TUBING RESETTABLE WELL PACKER

A tubing string resettable packer is conditioned for initial wireline installation in a well utilizing an adapter within a mandrel carrying the slip assembly of the packer and frangible connecting means between the sealing assembly and mandrel to place the sealing assembly in an alternate transport condition for first being set by means of a wireline device. Thereafter, the tubing string may be connected to the packer downhole to release the packer for resetting in a different position.

DOWNHOLE TOOL

A downhole tool (10) comprises a body (12) adapted to be incorporated in a drill string. The body defines a bore (20) and having a valve arrangement including a flow port (18) in the wall of the body and a valve element (22) biased towards a position to open the port. The valve element is initially retained in a position to close the flow port (18) but can be released as required to allow the flow port to be opened. The tool may be utilized as a bypass sub or a dump sub. For use as a bypass sub, the body bore below the flow port may be closed or restricted.

DOWNHOLE LATCH

A progressive cavity pump pumps liquid downhole to a lower formation past a packer set in a casing of a wellbore. The rotor of the pump is axially restrained by a bearing assembly spaced below the pump for controlling uphole reactive loading on the rotor. Preferably the rotor is releasably coupled to the bearing assembly for release and recovery of the rotor from the bearing assembly. Such a releasable coupling is a latch comprising a plunger telescopically and releasably coupled with a housing using a dog and track arrangement, the dog and track utilizing the telescoping action to actuate the coupling and releasing of the latch.

PACKER ASSEMBLY

Downhole Actuating Apparatus

A mechanical counting device for actuating a plurality of output devices, the device comprising: linear indexing means adapted to count a plurality of actuating signals and to cause actuation of the output devices when a predetermined number of actuating signals for each output device has been received, wherein the mechanical counting device is adapted to cause actuation of a particular output device when a different predetermined number of actuating signals has been received such that the output devices are sequentially actuable.

Method to restrict the number of cycles in a continuous j-slot in a downhole tool

A mechanism for use in a wellbore servicing tool includes a continuously rotating ring within a servicing tool, and a limiting mechanism configured to engage the ring and lock the ring upon a predetermined degree of rotation of the ring. The mechanism may comprise a portion of an actuation assembly for use in a wellbore.

Completion Method for Stimulation of Multiple Intervals

A technique provides for stimulating or otherwise treating multiple intervals/zones of a well by controlling flow of treatment fluid via a plurality of flow control devices. The flow control devices are provided with internal profiles and flow through passages. Mechanical darts are designed for engagement with the internal profiles of specific flow control devices, and each mechanical dart may be moved downhole for engagement with and activation of the specific flow control device associated with that mechanical dart.

Subterranean well tools having nonmetallic drag block sleeves

Disclosed is a drag block assembly for use on a downhole tool for location in a cased wellbore. The tool has a hollow mandrel for suspension from a tubing string. The drag block, slips and packing elements mounted on the mandrel are moveable between the run and set positions by movement of the drag block, while engaging a lug on the mandrel. The drag block assembly comprises longitudinally spaced rings comprising resilient material connected together by longitudinally extending members.

Indexing Sleeve for Single-Trip, Multi-Stage Fracing

A flow tool has a sensor that detects plugs (darts, balls, etc.) passing through the tool. An actuator moves an insert in the tool once a preset number of plugs have passed through the tool. Movement of this insert reveals a catch on a sleeve in the tool. Once the next plug is deployed, the catch engages the plug on the sleeve so that fluid pressure applied against the seated plug through the tubing string can move the sleeve. Once moved, the sleeve reveals ports in the tool communicating the tool's bore with the surrounding annulus so an adjacent wellbore interval can be stimulated. The actuator can use a sensor detecting passage of the plugs through the tool. A spring disposed in the tool can flex near the sensor when a plug passes through the tool, and a counter can count the number of plugs that have passed.

Apparatus and Method to Remotely Control Fluid Flow in Tubular Strings and Wellbore Annulus

A method and apparatus is disclosed for remotely and selectively controlling fluid flow through tubular string disposed within a wellbore and further control fluid flow between the tubular string inner flow passage and the annular flow passage. The present invention further discloses a method of selectively and remotely receiving and interpreting a form of command or information at a desired apparatus within the wellbore caused by the operator on earth surface.

Apparatus, Systems and Methods for a Flow Control Device

A flow control device for control of fluid flow through a tubular member comprises a control chamber having a piston disposed therein, where the piston is moveable from an open piston position to a closed piston position by the application of a first fluid pressure, and a valve chamber having a valve therein, where the valve is moveable from a closed valve position to an open valve position by the application of a second fluid pressure. A seal preventing fluid flow through the control chamber into the tubular member is formed in the closed piston position, and a flow path through the valve chamber and into the tubular member is formed in the open valve position.

Downhole fishing tool and method of use

The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position.

APPARATUS, SYSTEMS AND METHODS FOR COMPLETION OPERATIONS

A bottomhole assembly (BHA) having a shifting tool and housing for shifting an uphole-to-open sleeve of a sleeve of a shorter length downhole sleeve assembly to an open position, and optionally to a closed position. Sleeve-engaging elements of the BHA are coordinated to direct the sleeve-engaging elements into a tool-engaging profile of the sleeve, excluding other annular variations in the casing string. The BHA has an improved dual J-Mechanism situated between the shifting tool and housing to permit new additional shifting options which results in fewer overall shifting cycles of the BHA when used with the shift uphole-to-open, shorter-length sleeve assembly. The shortened sleeve assembly is incorporated into a casing string and is relatively short in length when compared with conventional sleeve assemblies. 1. A shifting tool for sleeve valves along a wellbore , each sleeve valve having a sleeve housing having a bore fit with an axially shiftable sleeve within , the sleeve having an annular sleeve profile formed therealong , the shifting tool comprising:a first housing portion having a first shifting mechanism;a second housing portion having a second shifting mechanism, the second housing portion telescopically connected to the first housing portion and adapted for axially telescoping between a collapsed position and an extended position;a drag block connected to the second housing portion and adapted for resisting axial movement the second housing portion in the wellbore;a mandrel having a first shifting member adapted to cooperate with the first shifting mechanism, a second shifting member adapted to selectably cooperate with the second shifting mechanism, and a retaining member;one or more sleeve engagement members supported on one or more pivotable arms, the one or more arms supported by the first housing portion, each of the one or more pivotable arms being radially actuable by the retaining member between at least a radially outward position and a radially ...

DOWNHOLE APPARATUS

Downhole Apparatus and Method For Providing Zonal Isolation. There is provided a sandscreen joint () capable of providing zonal isolation. The ends of the portion of the () are capable of extension on activation of the sandscreen (), including transition areas (), which are coated with an elastomer sleeve (). On activation of the sandscreen (), the sleeve () is pushed out into contact with the bore wall and serves to isolate the zone on one side of the activated sleeve () from the zone on the other side of the sleeve (). Thus, the provision of the sleeve () on the activated sandscreen () may prevent fluid from flowing axially along the bore between the bore wall and sandscreen. This may serve to protect the weave at the transition area (), preventing axial flow through the transition areas (). 136-. (canceled)37. A method of producing downhole apparatus , comprising:forming openings in a sheet, and thenat least partially closing the openings, the sheet being adapted to form an element of a tubular member.38. The method of claim 37 , comprising initially forming the openings in the sheet by any one of punching claim 37 , die casting and machining.39. The method of claim 37 , comprising closing at least one of the openings over a portion of the length of the opening or completely over the length of the opening.40. The method of claim 37 , wherein the tubular member is a shroud.41. The method of claim 40 , comprising utilising the shroud for an expandable sand screen or a sand screen which is otherwise configurable in an activated or extended configuration claim 40 , and on activation of the sand screen incorporating the shroud the at least partially closed openings open to permit fluid to flow in through the shroud.42. The method of claim 37 , comprising using the tubular member to provide a degree of protection for a filter member during run-in of the sand screen.43. The method of claim 37 , comprising providing the tubular member with a smooth outer surface for ...

SLEEVE VALVES, SHIFTING TOOLS AND METHODS FOR WELLBORE COMPLETION OPERATIONS THEREWITH

A shift uphole-to-open sleeve assembly is provided for insertion along a tubular string for multi-stage, selectable wellbore treatment. The sleeve assemblies are very short in length, being too short for in-sleeve engagement, and instead have a downhole shoulder engageable for opening using dogs of a conventional shifting tool. Use of a common J-mechanism having four axial inappropriately places the sealing packer of a downhole tool above the sleeve ports. Multiple extra J-mechanism cycles are required to position the packer downhole thereof. Herein a modified downhole tool is disclosed including a biased repositioning sub to eliminate many of the extra tool cycles. In embodiments the short sleeve can replace casing collars. 1. A completion string accessing a downhole formation comprising:a tubular string comprising a plurality of tubulars, at least some of which are connected by sleeve assemblies for selectable fluid communication from the tubular string to the formation;each sleeve assembly comprising a sleeve housing having a housing bore and one or more ports to the formation formed through the housing; anda sleeve fit slidably to the housing bore and having a sleeve bore, the sleeve being slidable from a downhole closed position, in which the one or more ports are blocked by the sleeve, to an uphole open position in which the one or more ports are open;an annular recess formed in the housing bore downhole of the sleeve and having a diameter greater than that of the sleeve bore, the sleeve having a downhole engagement shoulder extending radially into the housing bore.2. The completion string of wherein:each of the one or more ports have an axial extent; andthe sleeve has a sleeve length between about 2.5 and about 3 times the axial extent of the one or more ports.3. The completion string of wherein:the axial extent of the one or more ports is about 1 inch; andthe sleeve length is between about 2.5 and about 3 inches.4. The completion string of wherein:the sleeve ...

MODE SELECTOR FOR A DOWNHOLE TOOL

Embodiments herein relate to apparatus for selecting between direct manipulations of a downhole tool and shifting of the operational mode of a downhole tool, and more particularly to a mode selector tool coupled with a J-Slot mechanism for the downhole tool, the selector enabling either an unimpeded shifting of, or a locking, of the J-Slot mechanism and connected downhole tool. 1. A J-Slot mechanism mode selector for a downhole tool comprising:a J-Slot housing having a J-Profile having at least an uphole stop profile and a downhole stop profile;a J-Slot mandrel extending axially along the J-Slot housing and movable axially therethrough, the J-Slot mandrel having a pin for following the J-Profile;a selector housing coupled to the J-Slot housing, and a selector mandrel extending axially along the selector housing and coupled to the J-Slot mandrel; and in the free movement setting, the pin moves substantially unimpeded along the J-Profile; and', 'in the restrained movement setting, the pin is locked in a position along the J-Profile., 'a mode controller for controlling the axial movement of the selector mandrel within the selector housing between a free movement setting and a restrained movement setting wherein'}2. The mode selector of claim 1 , wherein the mode controller has a time delay between the free movement setting and the restrained movement setting.3. A J-Slot mechanism mode selector for a downhole tool conveyed on a conveyance string comprising:a J-Slot housing adapted for coupling the mode selector to the downhole tool, the J-Slot housing having a J-Profile having at least an uphole stop profile and a downhole stop profile; and—a J-Slot mandrel connected to the downhole tool and operable with the conveyance string and extending axially along the J-Slot housing, the J-Slot mandrel having a pin for following the J-Profile;a selector housing coupled to the J-Slot housing, and a selector mandrel extending axially along the selector housing and coupled to the J- ...

TOP-DOWN FRACTURING SYSTEM

A valve for use in a wellbore includes a housing including a housing port, a slidable closure member disposed in a bore of the housing and including a closure member port, and a seal disposed in the housing, wherein the closure member includes a first position in the housing where fluid communication is provided between the closure member port and the housing port, and a second position axially spaced from the first position where fluid communication between the closure member port and the housing port is restricted, wherein, in response to sealing of the bore of the housing by an obturating member sealingly engaging the seal, the closure member is configured to actuate from the first position to the second position. 1. A valve for use in a wellbore , comprising:a housing comprising a housing port;a slidable closure member disposed in a bore of the housing and comprising a closure member port; anda seal disposed in the housing;wherein the closure member comprises a first position in the housing where fluid communication is provided between the closure member port and the housing port, and a second position axially spaced from the first position where fluid communication between the closure member port and the housing port is restricted;wherein, in response to sealing of the bore of the housing by an obturating member sealingly engaging the seal, the closure member is configured to actuate from the first position to the second position.2. The valve of claim 1 , wherein the closure member comprises a sleeve.3. The valve of claim 1 , wherein the closure member comprises a third position in the housing axially spaced from the first position and the second position where fluid communication between the closure member port and the housing port is restricted.4. The valve of claim 3 , wherein the first position of the closure member is disposed axially between the second position and the third position.5. The valve of claim 3 , wherein claim 3 , in response to sealing of ...

Mechanically actuated device positioned below mechanically actuated release assembly utilizing j- slot device

A tool string carrying an external tool, such as a liner hanger, on a release mechanism is lowered into the wellbore. Interlocking lugs and J-slot profile, defined between the exterior surface of the mandrel and interior surface of the release mechanism, allow relative movement of release mechanism and mandrel without releasing the release mechanism. The relative movement allows mechanical operation of a valve or other tool positioned below the release mechanism. Weight-down and rotation of the tool string and mandrel actuates the lower valve assembly by turning a sleeve into alignment with cooperating members of the mandrel. The sleeve, no longer constrained, moves longitudinally in response to a biasing mechanism. Movement of the sleeve allows closure of the valve. After actuation of the valve tool, further weight-down releases the release mechanism from the carried tool.

Remote Hydraulic Control of Downhole Tools

A well tool apparatus comprises a control arrangement configured to control response of the downhole tool by varying downhole drilling fluid conditions. The control arrangement includes a valve piston longitudinally slidable in a generally tubular controller housing that is in operation substantially co-axial with the wellbore, to open or close a valve port to a fluid flow connection between the drill strings interior and the tool. A latch mechanism is configured to latch the valve piston in an activated mode and/or a deactivated mode. Unlatching of the valve piston can be effected by displacement thereof in a particular axial direction to a mode change position. A stay member is automatically displaceable in the particular actual direction under hydraulic actuation responsive to above-threshold drilling fluid conditions, to obstruct movement of the valve piston under hydraulic actuation to the mode change position. The stay member can include a lock piston carrying a ball locking mechanism for obstructing axial movement of the valve piston. 1. An apparatus comprising:a generally tubular housing configured for incorporation in a drill string which is to extend longitudinally along a borehole, the housing defining a longitudinally extending bore configured to convey drilling fluid through the housing;a valve port configured for connection to a hydraulic tool activation mechanism of a tool incorporated in the drill string;a valve piston that is longitudinally displaceable in the housing and that is configured to dispose the valve port from a closed condition to an open condition by longitudinal displacement of the valve piston in an opening direction, the valve port in the open condition permitting a fluid connection between the bore and the tool activation mechanism; an activated mode in which the valve port is in the open condition upon application of drilling fluid pressures at or substantially above tool activation levels, and', 'a deactivated mode in which the ...

DOWNHOLE SLEEVE ASSEMBLY AND SLEEVE ACTUATOR THEREFOR

A bottom hole actuator tool for locating and actuating one or more sleeve valves spaced along a completion string. A shifting tool includes radially extending dogs at ends of radially controllable, and circumferentially spaced support arms. Conveyance tubing actuated shifting of an activation mandrel, indexed by a J-Slot, cams the arms radially inward to overcome the biasing for in and out of hole movement, and for releasing the arms for sleeve locating and sleeve profile engagement. A cone, movable with the mandrel engages the dogs for positive locking of the dogs in the profile for sleeve opening and closing. A treatment isolation packer can be actuated with cone engagement. The positive engagement and compact axial components results in short sleeve valves. 1. A treatment system comprising:a completion string having a plurality of sleeve valves therealong, each sleeve valve having a sleeve housing and an axially shiftable sleeve, each sleeve having an annular profile formed intermediate the sleeve; and an activation mandrel connected to a J-Slot mechanism having a J-Pin operable in a J-Slot housing and a drag block for restraining the housing,', 'one or more dogs movable axially along the activation mandrel and radially actuable between a radially outward biased position, a sleeve profile-engaged position, and a radially inward collapsed position,', 'a cone movable axially along the activation mandrel between two positions, an engaged position with the dogs to lock them in the profile-engaged position and disengaged position, and', "a packer for sealing to the sleeve, the packer sealing to the sleeve in the cone's engaged position, wherein"], 'a shifting tool having'}the axial length of the sleeve valve is about the axial length of the packer, cone and dogs.2. The treatment system of claim 1 , wherein the J-slot mechanism comprises a profile having:a first intermediate downhole position to shift the dogs to the radially inward collapsed position without engaging ...

DOWNHOLE FISHING TOOL AND METHOD OF USE

The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position. 1. A method , the method comprising:sealing a first area inside a casing in a wellbore from a second area in the casing; at least one packer element for engaging a casing in a wellbore to isolate one area in the casing from another;', 'at least one slip element for engaging the casing and maintaining a position of the downhole tool in the wellbore; and', 'a mandrel slidably disposed within the at least one packer element and the at least one slip element, the mandrel having at least one port disposed therein above the at least one packer element when the mandrel is in a first position in the downhole tool and the at least one port disposed in the mandrel is disposed below all components of the at least one packer element when the mandrel is in a second position, the mandrel being fluidically open when the mandrel is in the first and second position;, 'attaching a part of a fishing tool to a stuck tool in the wellbore, the fishing tool comprisingremoving a substantial amount of fluid from the second area in the casing; andfreeing the stuck tool from the wellbore.2. The method of further comprising the steps of determining a location of the stuck tool and positioning the downhole tool a predetermined from the stuck tool.3. The method of further comprising the step ...

FISH RETRIEVAL FROM WELLBORE

An apparatus includes a housing, engagement slips, a tubular, a taper tap, a pin, and a slip activation member. The housing includes a profile that defines a path including a first end and a second end. The engagement slips are attached to the housing. The tubular passes through an opening of the housing. The taper tap is rotatable and connected to the housing. The pin is connected to the tubular and received by the profile of the housing. The tubular is translatable with respect to the housing based on the pin translating along the path defined by the profile. The slip activation member is connected to the tubular. The slip activation member is configured to move each of the engagement slips radially outward with respect to the housing when the pin translates to the second end of the path. 1. An apparatus comprising:a housing comprising a profile, the profile defining a path comprising a first end and a second end;a plurality of engagement slips attached to the housing;a tubular passing through an opening of the housing;a rotatable taper tap connected to the housing;a pin connected to the tubular and received by the profile of the housing, wherein the tubular is translatable with respect to the housing based on the pin translating along the path defined by the profile; anda slip activation member connected to the tubular, wherein, when the pin translates to the second end of the path, the slip activation member is configured to move each of the engagement slips radially outward with respect to the housing.2. The apparatus of claim 1 , comprising a motor disposed within the housing claim 1 , wherein the motor is configured to rotate the rotatable taper tap.3. The apparatus of claim 1 , wherein claim 1 , when the pin translates to the second end of the path claim 1 , the slip activation member is configured to cause each of the engagement slips to protrude radially from the housing.4. The apparatus of claim 2 , comprising a sealing member fixed to the tubular claim 2 ...

Multi-stage well isolation and fracturing

An activation tool is provided for use in a well isolation and stimulation string, The activation tool has a stationary seat for receiving a ball deployed down the string, a stationary inner body, a stationary outer body and a moving sleeve positioned between the stationary inner and stationary outer bodies and movable from an open position to a closed position by force of the ball against the seat. A first stage frac valve tool is also provided having a stationary outer body and an internal piston movable between an closed and an open position. A singular tool is further provided having a float shoe, an activation tool and integrally built with the float shoe and a first stage frac integrally built with the activation tool. A cased hole packer is further provided having an integral setting tool.

WELLBORE UNDERREAMING

An apparatus is positioned within a wellbore in a subterranean formation. The apparatus includes a housing, a guide shaft, a follower, multiple underreamer blades, and a hydraulic chamber. The housing defines a track including multiple catch points. The guide shaft is disposed within the housing. The follower protrudes radially outward form the guide shaft and is received by the track. The follower and the track are cooperatively configured to restrict movement of the guide shaft relative to the housing. A rate of flow to the guide shaft is adjusted to adjust a relative position of the guide shaft with respect to the housing until the follower is located at one of the catch points. A pressure within the hydraulic chamber is adjusted to adjust a level of radially outward protrusion of the underreamer blades. The underreamer blades are rotated to cut into the subterranean formation. 1. A system comprising:a housing defining a track comprising a plurality of catch points;a guide shaft disposed within an inner bore of the housing;a follower protruding radially outward from the guide shaft, the follower received by the track of the housing, wherein the follower and the track are cooperatively configured to restrict movement of the guide shaft relative to the housing to movement defined by the follower traveling along the track;a plurality of underreamer blades, each underreamer blade of the plurality of underreamer blades configured to rotate and cut into a subterranean formation;a hydraulic chamber disposed within the housing and coupled to the plurality of underreamer blades;a guide cone coupled to the hydraulic chamber, the guide cone configured to adjust a level of radially outward protrusion of the plurality of underreamer blades based on a pressure within the hydraulic chamber, wherein each configuration of the follower being located at one of the catch points of the plurality of catch points of the track corresponds to a different pressure within the hydraulic ...

Release Lugs for a Jarring Device

A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releaseably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel. 1. A release mechanism for a jarring tool having a mandrel comprising:a plurality of arcuate release lugs, each release lug including an inner surface and an outer surface;a plurality of axially spaced projections on the inner surface of the release lugs and a plurality of grooves on the outer surface of the release lugs;a mandrel having a plurality of axially spaced grooves on an outer surface of the mandrel; andan annular trigger sleeve surrounding the mandrel, the release lugs being positioned between the annular trigger sleeve and the mandrel, and one or more springs surrounding and in contact with the release lugs.2. A release mechanism for a jarring tool as claimed in wherein the projections have different axial widths.3. A release mechanism for a jarring tool as claimed in wherein the grooves in the mandrel have a width corresponding to the width of the projections on the inner surface of the release lugs.4. A release mechanism for a jarring tool as claimed in including three projections that are axially spaced from each other by a different distance.5. A release mechanism for a jarring tool as claimed in including at least three grooves in the outer surface of the mandrel claim 4 , the grooves being axially spaced from each other by a different distance.6. A jarring tool comprising:a housing;a mandrel having a plurality of axially spaced grooves;a trigger sleeve surrounding the mandrel;a plurality of axially extending arcuate release lugs having an inner and outer surface, each lug including a ...

Passively Motion Compensated Subsea Well System

A passively motion compensated subsea well system is described. Specifically, a passively motion compensated subsea well system comprising a tubing hanger running tool assembly. The tubing hanger running tool assembly comprises a pressure containing slip joint comprising an inner mandrel and an outer mandrel located concentrically such that the inner mandrel and outer mandrel slide relative to each other providing compression and extension along a linear axis with pressure containing seals located between the inner and outer mandrels, and a tubing hanger running tool. 1. A passively motion compensated subsea well system comprising:a marine riser suspended below the rig floor, coupled to a containment device;a wellhead assembly coupled to the containment device proximate to the top of the wellhead assembly; and a pressure containing slip joint comprising an inner mandrel and an outer mandrel located concentrically such that the inner mandrel and outer mandrel can slide relative to each other providing compression and extension along a linear axis and comprising pressure containing seals located between the inner and outer mandrels, and', 'a tubing hanger running tool., 'a tubing hanger running tool assembly suspended inside of one or more of the marine riser and the containment device from an upper tubing, the tubing hanger running tool assembly comprising2. The system of claim 1 , wherein the containment device is a mudline closure device or a blowout preventer.3. The system of claim 2 , wherein the containment device is a mudline closure device.4. The system of claim 3 , further comprising a surface BOP.5. The system of claim 1 , wherein the upper tubing is drill pipe or landing string.6. The system of claim 1 , wherein the tubing hanger running tool assembly further comprises an integral internal test tool located between the pressure containing slip joint and the tubing hanger running tool.7. The system of claim 1 , wherein the tubing hanger running tool assembly ...

Passively Motion Compensated Tubing Hanger Running Tool Assembly

A tubing hanger running too assembly comprising passive motion compensation and pressure testing capability is described. Specifically, a tubing hanger running tool assembly is described which comprises a tubing hanger running tool and a pressure containing slip joint comprising an inner mandrel and an outer mandrel located concentrically such that the inner mandrel and outer mandrel slide relative to each other providing compression and extension along a linear axis with pressure containing seals located between the inner and outer mandrels. 1. A tubing hanger running tool assembly comprising:a pressure containing slip joint comprising an inner mandrel and an outer mandrel located concentrically such that the inner mandrel and outer mandrel can slide relative to each other providing compression and extension along a linear axis and comprising pressure containing seals located between the inner and outer mandrels; anda tubing hanger running tool coupled to the pressure containing slip joint.2. The assembly of claim 1 , further comprising an integral internal test tool located between the tubing hanger running tool and the pressure containing slip joint.3. The assembly of claim 1 , further comprising a ported slick joint.4. The assembly of claim 3 , wherein the pressure containing slip joint is located between the ported slick joint and the tubing hanger running tool.5. The assembly of claim 1 , further comprising a shearable joint.6. The assembly of claim 3 , wherein the pressure containing slip joint is located between the shearable joint and the tubing hanger running tool.7. The assembly of claim 1 , wherein the pressure containing slip joint comprises a latching mechanism configured to stop the compression and extension of the slip joint.8. The assembly of claim 7 , wherein the latching mechanism is one or more of a shear pin claim 7 , a J-latch claim 7 , hydraulic pistons claim 7 , indexing nubs and channels claim 7 , and combinations thereof.9. The assembly of ...

Axially actuated external wellhead latch

A wellhead latch assembly may include one or more latches for attaching to a wellhead and allowing removal of the wellhead during a well abandonment process. The wellhead latch assembly may include an inner core coupled to the latches, and an outer sleeve for selectively latching and unlatching the latches to the wellhead. The inner core may abut the wellhead and can include a groove having circumferential and/or longitudinal features. The outer sleeve may include a pin which travels within the groove and a set of cut-outs for alignment with the latches. When the cut-outs align with the latches, the latches may expand radially outward and disengage the wellhead. As the outer sleeve moves axially or rotationally relative to the inner core, the latches may fall out of alignment with the cut-outs and move radially inwardly to engage or capture the wellhead.

APPARATUSES AND METHODS FOR LOCATING AND SHIFTING A DOWNHOLE FLOW CONTROL MEMBER

There is provided a downhole tool comprising a locator. The locator includes a wellbore coupler for becoming releasably retained relative to a locate profile; and a wellbore coupler release opposer configured for opposing release of the wellbore coupler from the retention relative to the locate profile. While the opposing of the release of the wellbore coupler from the retention relative to the locate profile is being effected by the wellbore coupler release opposer, relative displacement between the wellbore coupler release opposer and the wellbore coupler is effectible, with effect that the opposing is defeated. The locator also includes a displacement impeder for impeding the relative displacement between the wellbore coupler release opposer and the wellbore coupler. 1. A downhole tool comprising: a wellbore coupler for becoming releasably retained relative to a locate profile; and', 'a wellbore coupler release opposer configured for opposing release of the wellbore coupler from the retention relative to the locate profile;, 'a locator includingwherein the wellbore coupler and the wellbore coupler release opposer are co-operatively configured such that, while the opposing of the release of the wellbore coupler from the retention relative to the locate profile is being effected by the wellbore coupler release opposer, relative displacement between the wellbore coupler release opposer and the wellbore coupler is effectible, with effect that the opposing is defeated;anda displacement impeder for impeding the relative displacement between the wellbore coupler release opposer and the wellbore coupler; [ the wellbore coupler release opposer and the displacement impeder are co-operatively disposed in a first orientation;', 'the wellbore coupler is releasably retained relative to the locate profile;', 'release of the wellbore coupler from retention relative to the locate profile is being opposed by the wellbore coupler release opposer;', 'relative displacement between ...

Apparatus and Methods Setting a String at Particular Locations in a Wellbore for Performing a Wellbore Operation

An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a set down tool that includes a locating device configured to engage with an outer member at a selected location, a set down device configured to set down in a set down profile in the outer member when the set down device is activated, an alignment device for activating the set down device and a locking device that operates the alignment device to activate the set down device while maintaining the locating device engaged with the outer member.

Hydraulic underbalance initiated safety firing head, well completion apparatus incorporating same, and method of use

A firing head assembly is described. The firing head assembly includes a tubular housing, upper piston and lower pistons, and a compressible member arranged within a lumen of the tubular housing and positioned between the upper and lower pistons. According to an aspect, the assembly includes a safety assembly that includes a sleeve having a zigzag shaped slot therein. The safety assembly may include a key that radially extends from a surface of one of the pistons, through the zigzag shaped slot. The distance between the upper and lower pistons may be adjusted by adjusting a pressure inside the tubular housing and a second pressure outside the tubular housing. The upper and lower pistons may function to operatively adjust the arrangement of the key within the zigzag shaped slot to activate the firing head assembly to either trigger an explosive reaction or to not trigger the explosive reaction.

CASING SCRAPER ACTIVATED AND DEACTIVATED DOWNHOLE

A casing scraper can include extendable scraper elements, and an actuator that extends the scraper elements after the actuator retracts the scraper elements. The actuator extends the scraper elements and retracts the scraper elements after application of respective pressure differentials in a well. A method of operating a casing scraper can include extending scraper elements into contact with an interior surface of a casing after a predetermined pressure differential is applied without obstructing an interior flow passage, and then retracting the scraper elements after another predetermined pressure differential is applied. A well system can include a casing scraper with one or more extendable scraper elements, and an actuator that operates in response to manipulation of pressure differentials. The actuator operates the casing scraper only after at least a predetermined pressure differential has been applied for at least a predetermined period of time. 1. A casing scraper for use with a subterranean well , the casing scraper comprising:one or more extendable scraper elements configured to extend into cleaning contact with an interior surface of a casing in the well; andan actuator that extends the scraper elements in the well after the actuator retracts the scraper elements in the well, and wherein the actuator extends the scraper elements and retracts the scraper elements after application of respective pressure differentials in the well.2. The casing scraper of claim 1 , in which the pressure differentials are applied between an interior and an exterior of the actuator.3. The casing scraper of claim 1 , in which the actuator comprises a metering device that delays actuation of the casing scraper in response to the pressure differentials.4. The casing scraper of claim 3 , in which the metering device gradually transfers fluid through a restrictor element that provides communication between fluid chambers of the actuator.5. The casing scraper of claim 3 , in which ...

Activation and Control of Downhole Tools Including a Non-Rotating Power Section Option

A system and method to control fluid flow to downhole tools and equipment, and to allow formation testing and sampling operations is disclosed. The system includes an actuator assembly that may be mechanically or electrically activated to operate a flow diverter assembly. The flow diverter assembly may divert fluid flow to the annulus of the wellbore, to the stator of a power section, through a by-pass bore in a rotor of the power section, or any combination thereof. In the mechanically actuated actuator assembly, the actuator assembly is activated by pressure changes in the fluid introduced by cycling the pumps at the surface; and in the electrically actuated actuator assembly, the actuator assembly is activated by downlinks sent from a surface control unit or computer at the surface. 1. A control device for a downhole tool in a wellbore , the control device comprising:a tubular housing having a first end and a second end with an annulus port in the tubular housing and an internal flow annulus defined in the tubular housing between the annulus port and the second end of the tubular housing;a sleeve disposed within the housing between the port and the first end of the tubular housing, the sleeve having a first end, a second end, an outer surface having a groove formed therein, wherein the sleeve is axially and rotatably moveable relative to the tubular housing;a flow diverter assembly interconnected with the sleeve, the flow diverter assembly disposed within the tubular housing between the sleeve and the second end of the tubular housing, the flow diverter assembly movable between a first position and a second position, wherein the flow diverter is in fluid communication with the annulus port in one position and in fluid communication with the internal flow annulus in the other position, a follower having a pin extending into the groove of the sleeve, the follower fixed relative to axial and rotational movement of the sleeve, wherein the sleeve is movable relative ...

Release Lugs for a Jarring Device

A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releaseably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel.

PRESSURE CYCLE DEVICE

Provided is a pressure cycle actuation assembly. The pressure cycle actuation assembly, in one aspect, includes a housing, a reciprocating piston located within the housing and defining first and second fluid chambers, and a check valve positioned between the first and second fluid chambers, the check valve permitting fluid flow from the first fluid chamber to the second fluid chamber but preventing fluid flow from the second fluid chamber to the first fluid chamber. The A pressure cycle actuation assembly, according to this aspect, further includes a flow restrictor positioned between the first and second fluid chambers, the flow restrictor restricting fluid flow between the first fluid chamber and the second fluid chamber, and a rotating collet coupled to the reciprocating piston, the rotating collet translating reciprocal axial motion of the reciprocating piston into one-direction rotation and axial lengthening or shortening of the rotating collet relative to the reciprocating piston. 1. A pressure cycle actuation assembly , comprising:a housing;a reciprocating piston located within the housing and defining first and second fluid chambers;a check valve positioned between the first and second fluid chambers, the check valve permitting fluid flow from the first fluid chamber to the second fluid chamber but preventing fluid flow from the second fluid chamber to the first fluid chamber;a flow restrictor positioned between the first and second fluid chambers, the flow restrictor restricting fluid flow between the first fluid chamber and the second fluid chamber; anda rotating collet coupled to the reciprocating piston, the rotating collet translating reciprocal axial motion of the reciprocating piston into one-direction rotation and axial lengthening or shortening of the rotating collet relative to the reciprocating piston.2. The pressure cycle actuation assembly as recited in claim 1 , further including a stationary profiled ring claim 1 , the stationary profiled ...

APPARATUSES AND METHODS FOR LOCATING AND SHIFTING A DOWNHOLE FLOW CONTROL MEMBER

There is provided a downhole tool comprising a locator. The locator includes a wellbore coupler for becoming releasably retained relative to a locate profile; and a wellbore coupler release opposer configured for opposing release of the wellbore coupler from the retention relative to the locate profile. While the opposing of the release of the wellbore coupler from the retention relative to the locate profile is being effected by the wellbore coupler release opposer, relative displacement between the wellbore coupler release opposer and the wellbore coupler is effectible, with effect that the opposing is defeated. The locator also includes a displacement impeder for impeding the relative displacement between the wellbore coupler release opposer and the wellbore coupler. 127-. (canceled)28. A downhole tool , deployable within a wellbore , the downhole tool comprising:a first tool configured to co-operate with a first wellbore-interacting feature of the downhole tool, for establishing a first wellbore-interacting configuration; anda second tool (sub-assembly) configured to co-operate with a second wellbore-interacting feature of the first tool (sub-assembly), for establishing a second wellbore-interacting configuration; 'the first tool (sub-assembly) and the second tool (sub-assembly) are coupled with effect that, while the first tool is co-operating with the first wellbore-interacting feature such that the first wellbore-interacting configuration is established, the second tool is rotatable, relative to the first tool, about the longitudinal axis of the wellbore for establishing the second wellbore-interacting configuration.', 'wherein29. The downhole tool as claimed in ; 'the rotatability of the second tool is independent of rotatability of the first tool.', 'wherein30. The downhole tool as claimed in ; 'the rotatability of the second tool, relative to the first tool, about a longitudinal axis of the wellbore, is based on torque effectuated in response to mediation ...

CASED BORE STRADDLE PACKER

A cased bore straddle packer has an upper unload sub sleeve with fluid ports that are selectively aligned with corresponding ports in an upper unload sub mandrel component and a lower unload sub sleeve with fluid ports that are selectively aligned with corresponding ports in a lower unload sub mandrel component to permit fluid to be selectively dumped from the straddle packer. Control of the alignment of the respective ports is effected by manipulating an auto-J ratchet machined into a multicomponent mandrel of the straddle packer. The auto-J ratchet is controlled from the surface using completion string pull and push manipulations. 1. A cased bore straddle packer comprising:a multicomponent mandrel that extends from an upper end to a lower end of the cased bore straddle packer, the multicomponent mandrel having a completion string connection mandrel component at the upper end of the straddle packer to permit the connection of a completion tubing string to the straddle packer, an upper packer element mandrel component with an upper packer element piston, and a lower packer element piston mandrel component with a lower packer element piston;an upper packer element adapted to surround the multicomponent mandrel uphole of a flow activation mandrel component and a lower packer element adapted to surround the multicomponent mandrel downhole the flow activation mandrel component;an upper packer element compression sleeve uphole of the upper packer element, the upper packer element compression sleeve adapted to reciprocate on the upper packer element mandrel component, and a lower packer element compression sleeve adapted to reciprocate on the lower packer element piston mandrel component downhole the lower packer element;an auto-J ratchet groove in the multicomponent mandrel downhole of the lower packer element, the auto-J rachet groove having a slip engage notch adapted to permit string weight on the completion tubing string to force the multicomponent mandrel downhole ...

Casing Removal Tool And Methods Of Use For Well Abandonment

Systems and methods for removing casing from a wellbore including a casing removal tool that includes a tubular body configured to contain a thermite fuel mixture configured to initiate into a molten thermite fuel. The casing removal tool also includes a nozzle array having a plurality of nozzles positioned on an external surface of the tubular body. The nozzle array is configured to impinge the molten thermite fuel from within the tubular onto the wellbore casing. The casing removal tool also includes an orientation lug configured to anchor into a downhole orientation tool.

STRADDLE PACKER WITH FLUID PRESSURE PACKER SET AND AUTOMATIC STAY-SET

A straddle packer has a floating auto-J sleeve that automatically shifts the straddle packer from a run-in condition to a stay-set condition after pumping of high-pressure fluid into the straddle packer in excess of a predetermined pump rate is terminated. In the stay set condition, packer elements of the straddle packer remain in sealing contact with a well casing or well bore into which the straddle packer has been run. 1. A straddle packer with fluid pressure packer set and automatic stay-set , comprising:a hydraulic piston adapted to urge the straddle packer to a set condition in response pumped fluid pressure, the hydraulic piston having a piston mandrel and a piston cylinder that surrounds the piston mandrel;a floating auto-J sleeve adapted to rotate on the piston mandrel but constrained from axial movement on the piston mandrel, the floating auto-J sleeve including a continuous auto-J groove in an outer periphery thereof, the continuous auto-J groove including a plurality of auto-J groove run-in slots and a plurality of auto-J groove stay-set slots; anda plurality of auto-J pins installed in the piston sleeve, the piston sleeve reciprocating with respect to the piston mandrel in response to the pumped fluid pressure, and the plurality of auto-J pins being respectively adapted to be received in and slide within the continuous auto-J groove as the piston sleeve reciprocates with respect to the piston mandrel.2. The straddle packer as claimed in wherein the auto-J sleeve is constrained from axial movement by a piston connected to the piston mandrel and a lower packer element compression bell connected to the piston mandrel.3. The straddle packer as claimed in wherein first and second packer elements of the straddle packer are in a relaxed condition when the respective auto-J pins are in the auto-J run-in slots.4. The straddle packer as claimed in further comprising a plurality of auto-J groove pressure-set slots in the continuous auto-J groove.5. The straddle ...

RELEASABLE TOOL FOR EFFECTING COUPLING WITHIN A WELLBORE

There is provided a connecting device includes first and second device counterparts. The first device counterpart and the second device counterpart are co-operatively configured such that: releasable coupling between the first device counterpart and the second device counterpart is effectible, while the first device counterpart is releasably coupled to the second device counterpart in a releasably coupled position: (i) displacement of the first device counterpart, relative to the second device counterpart, along an axis in a first direction, is prevented or substantially prevented; and (ii) the first device counterpart is displaceable, relative to the second device counterpart, along an axis in a second direction that is opposite, or substantially opposite, to the first direction, for effecting in release of the first device counterpart from the coupling to the second device counterpart, with effect that the first device counterpart becomes disposed in a released position. The release of the first device counterpart from the releasable coupling to the second device counterpart is effectible in absence, or substantial absence, of torque applied to the first device counterpart about an axis that is parallel, or substantially parallel, to the central longitudinal axis of the first device counterpart. 184-. (canceled)85. A reservoir fluid conduction assembly for disposition within a wellbore string , that is lining a wellbore that is extending into a subterranean formation , such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly , wherein the assembly comprises:a reservoir fluid-supplying conductor for receiving reservoir fluid from a downhole wellbore space of the wellbore;a flow diverter body comprising (a) a diverter body-defined reservoir fluid conductor for conducting reservoir fluid, that is supplied from the reservoir fluid-supplying conductor, to a reservoir fluid separation space of an ...

DOWNHOLE PACKER TOOL ENGAGING AND OPENING PORT SLEEVE UTILIZING HYDRAULIC FORCE OF FRACTURING FLUID

A downhole packer tool includes a center mandrel and a packer provided around the center mandrel. The tool further includes sleeve engaging members movable between extended and retracted positions to either engage with a port sleeve or allow the packer tool to pass by the sleeve without engagement. In a run mode of operation, the sleeve engaging members retract toward the center mandrel. In a set mode of operation, a hydraulic force of a fluid flowing through the wellbore in a downhole direction generates an outward force pushing the sleeve engaging members away from the center mandrel such that they engage with an adjacent port sleeve. Once engaged, hydraulic fluid pressure causes the packer to move the sleeve into an open position. While engaged with the sleeve, uphole force applied to the packer tool may also be used to move the sleeve into a closed position in a similar manner. 1. A downhole packer tool for use in a wellbore , the downhole packer tool comprising:a center mandrel;a packer provided around the center mandrel;a first cone provided around the center mandrel;a body provided around an outward-facing surface of the first cone and forming an inner area between the outward-facing surface of the first cone and an inward-facing surface of the body;a profile block within the inner area, the profile block being extendable and retractable through a hole in the body; anda spring between the profile block and the inward-facing surface of the body;wherein, in a run mode of operation, an inward force exerted by the spring retracts the profile block toward the center mandrel; andin a set mode of operation, a hydraulic force of a fluid flowing through the wellbore in a downhole direction pushes the first cone in the downhole direction relative to the profile block and an outward force exerted by the outward-facing surface of the first cone against the profile block overcomes the inward force of the spring and pushes the profile block away from the center mandrel ...

MECHANICAL ROTATING CONTROL DEVICE LATCH ASSEMBLY

A remotely and mechanically actuated RCD control tool adjusts at least one component of an RCD latch assembly between at least two settings. The mechanical RCD control tool comprises a rotational cylinder and a guide cylinder, the rotational cylinder configured to rotate in a rotational direction to adjust the RCD latch assembly from a first setting to a second setting and from the second setting to the first setting based on movement of the drive cylinder in a selected direction. Additional apparatus, methods, and systems are disclosed. 1. A system comprising: a latch adjustable between a latched configuration and an unlatched configuration, the latch configured to releasably couple a tool to the body;', 'a sealing element adjustable between a sealed configuration and an unsealed configuration, the sealing element configured to provide a seal between the body and the tool; and', 'a mechanical RCD control tool configured to adjust at least one component of the latch assembly between at least two settings based solely on mechanical engagement of components of the RCD control tool., 'a latch assembly configured to be inserted into a body of a rotating control device (RCD), the latch assembly comprising2. The system of claim 1 , wherein the mechanical RCD control tool is configured to adjust the at least one component of the latch assembly from a first setting to a second setting and from the second setting to the first setting.3. The system of claim 1 , wherein the mechanical RCD control tool comprises:a rotational cylinder comprising a plurality of rotational teeth, wherein the rotational cylinder is configured to rotate in a rotational direction to adjust the at least one component of the latch assembly;a drive cylinder comprising a plurality of drive teeth configured to engage the rotational teeth to urge the rotational cylinder against a bias element; anda guide cylinder comprising a plurality of angled edges configured to receive the rotational teeth and ...

DOWNHOLE STEERING SYSTEM AND METHODS

A downhole steering system includes a substantially tubular housing, a shaft positioned within the substantially tubular housing, a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing. The first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween. The system also includes at least one structure positioned axially between a the first and second bearing and being configured to extend from an exterior of the housing in response to pressure communicated to the chamber. 1. A downhole steering system , comprising:a substantially tubular housing;a shaft positioned within the substantially tubular housing and rotatable with respect thereto;a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing, wherein the first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween; andat least one extendable structure positioned axially between the first and second bearing and being configured to extend from an exterior of the housing in response to pressure communicated to the chamber.2. The downhole steering system of claim 1 , wherein pressure is communicated to the chamber via one or more flow passages defined in the first bearing.3. The downhole steering system of claim 2 , wherein the first bearing comprises an inner journal and an outer housing claim 2 , the inner journal and the outer housing defining a clearance therebetween that provides at least a portion of the one or more flow passages.4. The downhole steering system of claim 2 , wherein the second bearing defines one or more flow passages extending therethrough claim 2 , so as to allow pressure communication with the chamber across the second bearing.5. The downhole steering system of claim 4 , wherein the first bearing is configured to maintain a ...

Downhole fishing tool and method of use

The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position.

DIAGNOSTIC TOOL FOR WELL ABANDONMENT TOOL

A tool is provided for diagnosing the downhole source of a surface casing vent flow for remediation of an abandoned well. The tool is run into the bore, the tool having a stack of pleated rings slidably mounted on a tubular mandrel. The tool is actuated. One end of the stack is set to engage with the casing and the stack is compressed axially to expand the pleated rings expand the casing for diminishing casing/cement micro-cracks. If surface casing vent flow is reduced, the downhole source is identified for remediation and, if not reduced, the tool is released, traversed uphole and actuated again. 1. A downhole tool conveyed into a casing of a well on a string of tubulars extending downhole into the cased well from surface , comprising:a tubular mandrel releasably connected to the string of tubulars;a stack of pleated rings slidably mounted on the mandrel;a first compression plate slidably mounted on the mandrel at one end of the stack and having a slip cone;a second compression plate mounted on the mandrel at another end of the stack with the stack of pleated rings sandwiched therebetween; and a drag block and slips supported by the housing, and', 'a pin and slot assembly between the housing and the mandrel, the slot having a profile having at least a run-in-hole (RIH) for spacing the slips from the slip cone, a pull-out-of-hole (POOH) for spacing the slips from the slip cone, and a slip set (SET) position for engaging slips with the slip cone for axially compressing the pleated rings between the first and second compression rings for radially expanding the pleated rings., 'a releasable slip assembly comprising a housing slidable over the mandrel for alternately releasing and compressing the stack of rings,'}2. The tool of claim 1 , wherein the mandrel has a stop formed thereon for spacing of the slips from the slip cone in the RIH and POOH positions.3. The tool of claim 1 , wherein in the released position claim 1 , the stack of pleated rings have a first diameter ...

MULTILATERAL MULTISTAGE SYSTEM AND METHOD

Provided herein is an intervention tool and a method for fracturing multiple lateral wellbores in a well system. The intervention tool, in one aspect, includes a radial outer housing, the radial outer housing forming an interior bore configured to flow fluid, and an expansion member coupled proximate an outer surface of the radial outer housing. The intervention tool according to this aspect further includes a sliding sleeve positioned along an interior surface of the radial outer housing and engageable with the expansion member, the sleeve including a collection of slots or catches configured to move the expansion member between a radially retracted position when the sliding sleeve is in a first linear position and a radially expanded position when the sliding sleeve is in a second linear position. 1. An intervention tool , comprising:a radial outer housing, the radial outer housing forming an interior bore configured to flow fluid;an expansion member coupled proximate an outer surface of the radial outer housing; anda sliding sleeve positioned along an interior surface of the radial outer housing and engageable with the expansion member, the sleeve including a collection of slots or catches configured to move the expansion member between a radially retracted position when the sliding sleeve is in a first linear position and a radially expanded position when the sliding sleeve is in a second linear position.2. The intervention tool as recited in claim 1 , wherein the plurality of slots or catches are a collection of J-slots in the sliding sleeve that engage one or more position pins associated with the radial outer housing.3. The intervention tool as recited in claim 2 , wherein the one or more J-slots include a first slot configured to move the expansion member to a first radially retracted position claim 2 , a second slot configured to move the expansion member to a second radially expanded position claim 2 , a third slot configured to move the expansion member ...

Wellbore actuators, treatment strings and methods

A wellbore tubing string assembly comprises: a string including an inner bore having an inner diameter and a plurality of tools installed along the string including a first tool and a second tool axially offset from the first tool along the string; the first tool includes: a first sleeve in the inner bore having an inner surface, the inner surface defining a first restriction diameter smaller than the inner diameter; a first sensor mechanism in communication with the first sleeve and responsive to an application of force against the first sleeve; the second tool includes; a second sleeve in the inner bore having an inner wall surface, the inner wall surface defining a second restriction diameter smaller than the inner diameter; a second sensor mechanism in communication with the second sleeve and responsive to an application of force against the second sleeve; and a sealing device having a diameter greater than the second restriction diameter and being deformable to be pushable through the second restriction diameter to apply a force against the second sleeve.

Dual direction j-slot tool

A multi-position tool for use at a downhole end of a conveyance string for operation in a casing string is provided. The tool comprises a mandrel connected to the conveyance string; an actuation housing slidably shiftable axially along the mandrel between an uphole position, at least one intermediate position and a downhole position; an uphole device operable between an activated position when the actuation housing is in the uphole position, and a deactivated position; and a downhole device operable between an activated position when the actuation housing is in the downhole position, and a deactivated position. Both the uphole and downhole devices are in their deactivated positions when the actuation housing is in the at least one intermediate position. The tool has a J-slot mechanism operable between the actuator housing and the mandrel for shifting the actuator housing between the uphole, at least one intermediate, and downhole positions.

Downhole Tool Actuator With Viscous Fluid Clearance Paths

A flow tube is axially moveable within an actuator body between a first axial position and a second axial position for actuating a downhole tool, such as for closing a subsurface safety valve. The flow tube includes an interior flow bore for conveying fluids from the tubing string through the actuator body. An external flow tube profile defined on the flow tube includes an upper shoulder for engagement with a wiper in the first axial position, a lower shoulder for engagement with the wiper in the second axial position, and a clearance path between the upper and lower shoulders for allowing viscous flow past the wiper when the flow tube is moved between the first and second axial positions. 1. A subsurface safety valve , comprising:a tool body positionable in a wellbore and having an upper end for coupling to a tubing string, a lower end, and a through bore between the upper and lower ends for conveying fluid;a valve closure element coupled to the lower end of the tool body and moveable between an open position and a closed position;a flow tube disposed in the tool body and axially moveable between a first axial position putting the valve closure element in the open position and a second axial position allowing the valve closure element to move to the closed position, the flow tube including an interior flow bore for conveying the fluid from the tubing string; andan external flow tube profile formed on the flow tube including an upper shoulder for engagement with a wiper in the first axial position, a lower shoulder for engagement with the wiper in the second axial position, and a clearance path between the upper and lower shoulders for allowing viscous flow past the wiper when the flow tube is in-between the first and second axial positions.2. The subsurface safety valve of claim 1 , wherein the clearance path comprises a plurality of axially-extending claim 1 , circumferentially-spaced channels along the external flow tube profile between the upper and lower ...

TESTABLE SLIDING SLEEVE VALVE

A sliding sleeve valve for use in a borehole includes an outer housing including a radial housing slot, a sliding sleeve slidably disposed in the outer housing, the sliding sleeve including a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot, an actuator housing coupled to the outer housing, wherein the actuator housing includes an actuator chamber defined by an inner surface, and wherein the actuator chamber is disposed between an inner surface and an outer surface of the actuator housing, and an actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions. 1. A sliding sleeve valve for use in a borehole , comprising:an outer housing comprising a radial housing slot;a sliding sleeve slidably disposed in the outer housing, the sliding sleeve comprising a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, axially spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot;an actuator housing coupled to the outer housing, wherein the actuator housing comprises an actuator chamber defined by an inner surface extending around a central axis of the actuator chamber, and wherein the actuator chamber is disposed radially between an inner cylindrical surface and an outer cylindrical surface of the actuator housing; andan actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions.2. The sliding sleeve valve of claim 1 , wherein the actuator assembly comprises:an ...

String Indexing Device to Prevent Inadvertent Tool Operation with a String Mounted Operating Device

An indexing tool is incorporated into a tubular string. The indexing tool is intended to function as a variable travel stop so that on initial landing other tools associated with the string will not extend to an operating position for tools that would otherwise operate on contact with relative movement. The indexing device can prevent a shifting device from engaging a valve operator when the index device initially lands on a support either during normal operation or in an emergency such as when shear rams have cut the string to allow it to fall so that a blowout preventer can be operated to engage opposed rams. In such an emergency the barrier valve operator will not be actuated and the string is later fished with the barrier valve closed. A pickup and set down force then allows the barrier valve to open when desired. 1. A device for use on a tubular string for selectively engaging a travel stop in an existing string that supports a subterranean tool and for selective operation of the subterranean tool , comprising:selectively relatively movable components, at least one of which further comprises a landing shoulder;said components configured to move relatively or not at all on initial contact of said landing shoulder to the travel stop such that the subterranean tool is not operated.2. The device of claim 1 , wherein:said components are connected to each other with a j-slot mechanism.3. The device of claim 1 , wherein:said components selectively assume a longer extension from said landing shoulder for subterranean tool operation.4. The device of claim 1 , wherein:said landing shoulder engages the travel stop upon said components free falling with at least a portion of the tubular string.5. The device of claim 1 , wherein:said landing shoulder engages the travel stop upon said components being moved from a surface location with the tubular string.6. The device of claim 3 , wherein:said landing shoulder has to contact the travel stop a second time to operate the ...

Rotating grip arms

A packer and apparatus for engaging the packer within a bore. The apparatus comprises a central body and a cone secured to the central body having an inclined surface oriented towards the second end and a collar translatable along the central body, the collar being located between the cone and the second end of the central body and a plurality of arms, each arm pivotally located relative to the collar around a periphery of the central body, arms extending between first and second ends and having gripping surfaces around an exterior surface thereof proximate to the first ends. The method comprises translating the central member of the body relative to a collar therearound so as to frictionally drag the collet arms against a well bore and engaging the cone upon the plurality of arms to pivot the plurality of anus into contact with a well bore wall.

DOWNHOLE TOOL ACTUATORS AND INDEXING MECHANISMS

A downhole tool control apparatus includes a control assembly, a stroking assembly, and a pocket sleeve positioned in an outer sub. The control assembly and stroking assembly are independently slidable axially within the outer sub. The control assembly and stroking assembly slide depending on the flow rate of fluid through the downhole tool actuator. The stroking assembly includes a spline barrel having a spline projection positioned within a spline pocket formed in the pocket sleeve. The pocket sleeve and control assembly include one or more ratchet teeth positioned in the pocket sleeve such that as the flow rate is changed between a high and a low flow rate, the spline projection engages the ratchet teeth until an actuated cycle is completed, allowing the downhole tool actuator to move to an actuation position. 1. A method for controlling a downhole tool using a downhole tool controller that is operatively coupled to the downhole tool , comprising at least the steps of:a) configuring the downhole tool controller in a first position by increasing a fluid flow through the downhole tool controller to a first high flow rate;b) configuring the downhole tool controller in a second position by lowering the fluid flow through the downhole tool controller from the first high flow rate to a first low flow rate;c) configuring the downhole tool controller in a third position by increasing the fluid flow through the downhole tool controller from the first low flow rate to a second high flow rate; andd) optionally, configuring the downhole tool controller in a fourth position by stopping fluid flow through the downhole tool actuator.2. The method of claim 1 , further including repeating steps a) and b) at least once before step d).3. The method of claim 2 , further including repeating step b) after step c) and then repeating step c) before step d).4. The method of wherein the downhole tool controller includes a control apparatus that defines a fluid flow path having a variable ...

MECHANICAL HAMMERING TOOL FOR USE IN OIL WELLS

The invention relates to a cable-operated hammering tool () for downhole operations, comprising an extended cylinder () with an axially through-going internal opening in the cylinder (), a hammering part () is arranged in a lower section of the cylinder () and is fitted with a detachable coupling for the connection with downhole equipment, a release strut () is arranged in the upper section of the cylinder () that is connected to a cable which is connected to a surface installation, the hammering part is detachably fastened to the cylinder () with the help of, at least, one locking body (). The release strut () is functionally connected to a force spring () for prestressing of this by moving in a first direction, and also functionally coupled to the, at least, one locking body () to be released from this by moving in an opposite direction. 1. A cable-operated hammering tool for downhole operations , the cable-operated hammering tool comprisinga cylinder with an axially through-going internal opening in the cylinder;a hammering part arranged in a first section of the cylinder;wherein the hammering part is fitted with a detachable coupling for connection with a downhole equipment;a release strut arranged in a second section of the cylinder, the release strut is adapted to be connected to a surface installation via a cable;wherein the hammering part is detachably coupled to the cylinder by at least one locking unit in a locked position of the locking unit; andwherein the cable operated hammering tool comprises a force spring that is in contact with the release strut for the pre-biasing of the release strut by movement of the release strut in a first direction, that the release strut is displaceable in a second opposite direction, the release strut being coupled to the locking unit, so that when the release strut is moving in the second direction it is displacing the locking unit from the locked position and thereby releasing the hammering part from the cylinder.2. The ...

CASED BORE STRADDLE PACKER

A cased bore straddle packer has an upper unload sub sleeve with fluid ports that are selectively aligned with corresponding ports in an upper unload sub mandrel component and a lower unload sub sleeve with fluid ports that are selectively aligned with corresponding ports in a lower unload sub mandrel component to permit fluid to be selectively dumped from the straddle packer. Control of the alignment of the respective ports is effected by manipulating an auto-J ratchet machined into a multicomponent mandrel of the straddle packer. The auto-J ratchet is controlled from the surface using completion string pull and push manipulations. 1. A straddle packer comprising:a multicomponent mandrel that extends from an upper end to a lower end of the cased bore straddle packer, the multicomponent mandrel having a completion string connection mandrel component at an uphole end of the straddle packer to permit the connection of a completion tubing string to the straddle packer;an upper unload sub sleeve with fluid ports that are selectively aligned with corresponding upper unload sub mandrel ports in an upper unload sub mandrel component of the multicomponent mandrel;a lower unload sub sleeve with fluid ports that are selectively aligned with corresponding lower unload sub mandrel ports in a lower unload sub mandrel component of the multicomponent mandrel;auto-J ratchet including an auto-J ratchet lug that engages an auto-J ratchet groove machined into the multicomponent mandrel, the auto-J ratchet groove having a neutral notch in which the respective fluid ports are aligned with the respective upper unload, sub mandrel ports and the lower unload sub mandrel ports to permit fluid to be unloaded from the straddle packer, and a slip engage notch in which the respective fluid ports are not aligned with the respective upper unload sub mandrel ports and the lower unload sub mandrel ports and fluid cannot be unloaded through the respective fluid ports.2. The cased bore straddle ...

REDUCED FRICTION J-LATCH DEVICE

In accordance with presently disclosed embodiments, systems and methods for selectively engaging, raising or lowering, and disengaging downhole equipment via a reduced friction J-latch mechanism is provided. The disclosed J-latch mechanism generally includes a J-latch receptacle including a cylinder having a slot formed therein, the slot having an open end exposed at one end of the cylinder and a truncated slot area at an opposite end of the slot from the open end. The J-latch mechanism also includes a J-latch lug member including a mounting portion with a lug disposed thereon for removably interfacing with the slot of the J-latch receptacle. The lug includes a bearing assembly to reduce friction between the slot and the lug while selectively engaging and disengaging the lug member from the receptacle. The disclosed J-latch mechanism may improve the efficiency of deployment, retrieval, and actuation of a wide range of oilfield equipment under heave conditions. 1. A system , comprising: a J-latch receptacle comprising a cylinder having a slot formed therein, the slot having an open end exposed at one end of the cylinder and a truncated slot area at an opposite end of the slot from the open end; and', 'a J-latch lug member comprising a mounting portion with a lug disposed thereon for removably interfacing with the slot of the J-latch receptacle, wherein the lug comprises a bearing assembly to reduce friction between the slot and the lug while selectively engaging and disengaging the J-latch lug member from the J-latch receptacle., 'a J-latch mechanism, comprising2. The system of claim 1 , wherein the bearing assembly comprises roller bearings claim 1 , tapered roller bearings claim 1 , needle roller bearings claim 1 , self-aligning bearings claim 1 , cylindrical roller bearings claim 1 , spherical roller bearings claim 1 , or carb toroidal bearings.3. The system of claim 1 , wherein the J-latch receptacle comprises a plurality of slots formed therein claim 1 , each ...

Downhole repeat micro-zonal isolation assembly and method

An assembly and method to repeatedly set and isolate multiple sections along a zone of interest in a single downhole trip is disclosed. The assembly includes an outer pipe and an inner pipe adapted to telescope along the outer pipe. After a first section of a zone of interest is isolated, the inner pipe may be telescoped up along the outer pipe, and then set to isolate a second section above the first section. This process may be repeated as desired to stimulate and/or test each desired section along a zone of interest. Once the inner pipe is completely telescoped inside the outer pipe, the inner pipe may be disconnected from the outer pipe via use of a disconnect assembly.

System and Method for Isolating a Section of a Well

A technique facilitates servicing of a subterranean formation by treating a specific section of a well. The technique utilizes a straddle packer conveyed downhole and then activated via coiled tubing. The straddle packer comprises a first, e.g. upper, packer and a second, e.g. lower, packer which are deployed downhole into the wellbore to the specific section of the wellbore proximate a target formation zone. Once properly located, the straddle packer is uniquely activated by compression and tension inputs applied via the coiled tubing. 1. A system for use in a wellbore , comprising:a coiled tubing; and a lower packer having a lower sealing element, lower slips, and a lower indexing mechanism;', 'an upper packer having an upper sealing element, upper slips, and an upper indexing mechanism; and', 'an injection mandrel having injection ports, the injection mandrel being coupled between the upper packer and the lower packer;, 'a straddle packer coupled to the coiled tubing, the straddle packer comprisingthe lower indexing mechanism and the upper indexing mechanism cooperating to selectively prevent or enable setting of the upper sealing element, upper slips, lower sealing element, and lower slips based solely on compression and tension inputs applied to the straddle packer via the coiled tubing.2. The system as recited in claim 1 , wherein the lower indexing mechanism comprises a lower J-slot indexer having a lower mandrel surrounded by a lower housing claim 1 , a multi-position profile claim 1 , and a plurality of pins moved between positions along the multi-position profile upon relative linear movement between the lower mandrel and the lower housing.3. The system as recited in claim 2 , wherein the upper indexing mechanism comprises an upper J-slot indexer having an upper mandrel surrounded by an upper housing claim 2 , a multi-position profile claim 2 , and a plurality of pins moved between positions along the multi-position profile upon relative linear movement ...

Downhole tool actuators and indexing mechanisms

A downhole tool control apparatus includes a control assembly, a stroking assembly, and a pocket sleeve positioned in an outer sub. The control assembly and stroking assembly are independently slidable axially within the outer sub. The control assembly and stroking assembly slide depending on the flow rate of fluid through the downhole tool actuator. The stroking assembly includes a spline barrel having a spline projection positioned within a spline pocket formed in the pocket sleeve. The pocket sleeve and control assembly include one or more ratchet teeth positioned in the pocket sleeve such that as the flow rate is changed between a high and a low flow rate, the spline projection engages the ratchet teeth until an actuated cycle is completed, allowing the downhole tool actuator to move to an actuation position.

Drill pipe string conveyed retrievable plug system

A drill pipe string conveyed retrievable plug system has a central through bore. The plug system includes a drill pipe string; a control section; a running tool with a connector at a lower end of a drill pipe string with the control section, and a top connector on a mechanical plug section with a bridge plug. The mechanical plug section includes a mandrel with the through bore, a ball valve arranged for closing the through bore, and a packer sleeve on the mandrel with slips and a packer element. The control section includes an electric supply, an electric control unit, and sensors connected to the electric control unit. The mechanical plug section includes a motor controlled by the electrical control unit. The motor is arranged to turn a selector ring to a selected first rotational position so as for allowing a piston sleeve to slide to an axial first stop position in order for opening to fluid channels through the mandrel from the through bore to the packer sleeve. The pressure in the through bore can be set to the pressure of the packer sleeve in a surrounding casing. 1. A drill pipe string conveyed retrievable plug system having a central through bore , said plug system comprising:a drill pipe string;a control section;a running tool with a connector at a lower end of a drill pipe string with said control section,a top stinger on a mechanical plug section with a bridge plug section, a mandrel with said through bore', 'a packer sleeve on said mandrel with slips and a packer element, 'said bridge plug section comprising'} an electrical supply;', 'an electric control unit;', 'sensors connected to said electric control unit,, 'said control section comprising'} 'a motor controlled by said electrical control unit,', 'said mechanical plug section further comprising'}said motor arranged for opening to fluid channels through said mandrel from said through bore to said packer sleeve,so as for allowing setting pressure in said through bore to pressure setting through said ...

Release Lugs for a Jarring Device

A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releasably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel. 1. A release mechanism for a jarring tool having a mandrel comprising:a housing,a plurality of arcuate release lugs, each release lug including an inner surface and an outer surface;a plurality of axially spaced projections on the inner surface of the release lugs and a plurality of grooves on the outer surface of the release lugs;a mandrel adapted for longitudinal movement within the housing and having a plurality of axially spaced grooves on an outer surface of the mandrel; andan annular trigger sleeve surrounding the mandrel, the release lugs being positioned between the annular trigger sleeve and the mandrel, and one or more springs surrounding and in contact with the release lugs.2. A release mechanism for a jarring tool as claimed in wherein the projections have different axial widths.3. A release mechanism for a jarring tool as claimed in wherein the grooves in the mandrel have a width corresponding to the width of the projections on the inner surface of the release lugs.4. A release mechanism for a jarring tool as claimed in including three projections that are axially spaced from each other by a different distance.5. A release mechanism for a jarring tool as claimed in including at least three grooves in the outer surface of the mandrel claim 4 , the grooves being axially spaced from each other by a different distance.6. A jarring tool comprising:a housing;a mandrel adapted for longitudinal movement within the housing and having a plurality of axially spaced grooves;a trigger sleeve surrounding ...

Force multiplyer used to actuate a ball valve

A rotating ball valve assembly includes a rotatable ball element. The rotatable ball element includes a first side portion, a second side portion, and a central passage. One of the first and second side portions includes first and second outwardly projecting pin elements. A sliding sleeve assembly includes a sliding sleeve member having a first guide track with a first force reducing profile associated with the first outwardly projecting pin element and a second guide track having a second force reducing profile associated with the second outwardly projecting pin element. The sliding sleeve member is shiftable relative to the first and second tubular members to selectively pivot the rotatable ball element between an open orientation and a closed orientation.

SHIFTING TOOL FOR A DOWNHOLE TOOL

A shifting tool is provided for locating and actuating downhole tools in a downhole tubular string, such as sleeve valves spaced along a completion string. The shifting tool includes dogs at ends of two or more radially controllable, and circumferentially spaced support arms. The arms are manipulated with an axially movable arm-constrictor spider for engaging radially variable cams on the sides of the arms. The spider includes cam follower tabs to cam the arms radially inward for in and out of hole movement, and for releasing the arms for sleeve locating and sleeve profile engagement. The tabs are radially inset from the arms to minimize obstruction of a tool annulus and interference damage when travelling along the downhole string. 1. A shifting tool for a downhole tool located in a tubular string extending downhole , comprising:an activation mandrel adapted for conveyance downhole into the tubular string;two or more arms, extending axially in an annulus formed between the activation mandrel and the tubular string, the arms spaced circumferentially about the mandrel and each arm having a base end and a dog at an opposing dog end, each arm being radially actuable, to position the dog end between a radially outward engagement position and a radially inward constricted position, and having a cam profile extending along each opposing side of the arm, the mandrel axially movable axially relative to the arms; anda constrictor spider movable with the mandrel and spokes extending radially from a hub and each spoke between the sides of adjacent arms of the two or more arms, each spoke having cam-engaging tabs extending circumferentially to slidably engage a side cam of adjacent arms for at least radial constraint of the arms, the tabs movable axially along the cam with the spider and mandrel to activate the arms between the engagement and constricted positions.2. The shifting tool of wherein the mandrel is sequenced between the radially outward engagement position and the ...

FISH RETRIEVAL FROM WELLBORE

An apparatus includes a housing, engagement slips, a tubular, a taper tap, a pin, and a slip activation member. The housing includes a profile that defines a path including a first end and a second end. The engagement slips are attached to the housing. The tubular passes through an opening of the housing. The taper tap is rotatable and connected to the housing. The pin is connected to the tubular and received by the profile of the housing. The tubular is translatable with respect to the housing based on the pin translating along the path defined by the profile. The slip activation member is connected to the tubular. The slip activation member is configured to move each of the engagement slips radially outward with respect to the housing when the pin translates to the second end of the path. 115-. (canceled)16. An apparatus comprising:a housing comprising an indented profile defining a path;a plurality of engagement slips attached to the housing;a tubular;a rotatable taper tap connected to the housing;a motor disposed within the housing, wherein the motor is configured to rotate the rotatable taper tap;a pin connected to the tubular and received by the indented profile of the housing, wherein the tubular is translatable with respect to the housing based on the pin translating along the path defined by the indented profile; anda slip activation member connected to the tubular, wherein, when the pin translates to an end of the path, the slip activation member is configured to move each of the engagement slips radially outward with respect to the housing.17. The apparatus of claim 16 , wherein claim 16 , when the pin translates to the end of the path claim 16 , the slip activation member is configured to cause each of the engagement slips to protrude radially from the housing.18. The apparatus of claim 16 , comprising a sealing member fixed to the tubular claim 16 , the sealing member configured to form a seal with an inner surface of the housing to isolate a portion of ...

SELECTIVE DOWNHOLE ACTUATOR

A selective downhole actuator comprising at least a first actuator position, a second actuator position and a third actuator position. The selective downhole actuator is reconfigurable between the first actuator position and the second actuator position. The selective actuator is selectively reconfigurable to the third actuator position by varying an operating parameter during a transition of the selective downhole actuator between the first and second actuator positions. 1. A selective downhole actuator comprising at least a first actuator position , a second actuator position and a third actuator position , wherein the selective downhole actuator is reconfigurable between the first actuator position and the second actuator position , and the selective downhole actuator is selectively reconfigurable to the third actuator position by varying an operating parameter during a transition of the selective downhole actuator between the first and second actuator positions.2. The selective downhole actuator of claim 1 , wherein the actuator comprises a downhole indexer such that the first claim 1 , second and third actuator positions comprise first claim 1 , second and third indexing positions respectively claim 1 , and wherein being selectively reconfigurable comprises being selectively indexable.3. (canceled)4. The selective downhole actuator of claim 1 , wherein at least one of:the selective downhole actuator is selectively reconfigurable to the third actuator position only by varying the operating parameter during the transition of the selective downhole actuator between the first and second actuator positions;the selective downhole actuator is selectively reconfigurable to the third actuator position by selectively varying the operating parameter during the transition according to a first predetermined pattern, sequence or procedure; andthe selective downhole actuator is cyclable between the first and second positions and only reconfigurable to the third position upon ...

APPARATUS AND METHOD FOR OPENING AND CLOSING IN MULTIPLE CYCLES A DOWNHOLE SLEEVE USING AN INTERVENTION TOOL

A downhole wellbore system is provided, comprising one or more downhole sleeves run on a liner; and an intervention tool deployable into the liner. The intervention tool is reciprocateable within the line and one or more downhole sleeves between any one or more positions selected from the group consisting of: downhole sleeve opening position, downhole sleeve closing position, pull uphole position, push downhole position, and setting in a blank section of the liner position. A method is further provided for manipulating an intervention tool in a liner comprising one or more downhole sleeves. The method comprises the steps of deploying an intervention tool into the liner and reciprocating the intervention tool between one or more positions selected from the group consisting of: downhole sleeve opening position, downhole sleeve closing position, pull uphole position, push downhole position, and setting in a blank section of the liner position. 1. A downhole wellbore system comprising:a. one or more downhole sleeves run on a liner; andb. an intervention tool deployable into the liner and into any one of said one or more downhole sleeves, said intervention tool comprising one or more slips, a packer and a collet selectively engagable in the inner surface of the downhole sleeve,wherein the intervention tool is reciprocateable within the line and one or more downhole sleeves between any one or more positions selected from the group consisting of: downhole sleeve opening position, downhole sleeve closing position, pull uphole position, push downhole position, and setting in a blank section of the liner position.2. The system of claim 1 , wherein the intervention tool is reciprocateable to a downhole sleeve opening position in which said the one or more slips are set against the inner surface of the downhole sleeve claim 1 , the packer is packed against the inner surface of the downhole sleeve claim 1 , and the downhole sleeve is openable by application of hydraulic pressure ...

TOOL FOR OPENING AND CLOSING SLEEVES WITHIN A WELLBORE

There is provided a bottomhole assembly for deployment within a wellbore string disposed within a wellbore, the wellbore string including a port and a flow control member, wherein the flow control member is displaceable relative to the port for effecting opening and closing of the port, comprising: a first mandrel; a second mandrel including a locator for becoming disposed within a locate profile of the wellbore string such that resistance to displacement of the second mandrel, relative to the locate profile, is effected, and such that locating of the bottomhole assembly within the wellbore string is thereby effected; a shifting tool including a first gripper surface and a second gripper surface; a first shifting tool actuator, translatable with the first mandrel; and a second shifting tool actuator, translatable with the first mandrel; wherein: the shifting tool is displaceable in response to urging by the first shifting tool actuator that is effected by downhole displacement of the first mandrel relative to the second mandrel, such that the first gripper surface is displaced outwardly to a first gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; the shifting tool is displaceable in response to urging by the second shifting tool actuator that is effected by uphole displacement of the first mandrel relative to the second mandrel, such that the second gripper surface is displaced outwardly to a second gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; and the second mandrel includes a retainer for limiting displacement of the shifting tool, relative to second mandrel, in both of downhole and uphole directions. 1. A bottomhole assembly for deployment within a wellbore string disposed within a wellbore , the wellbore string including a port and a flow control member , wherein the flow control member is displaceable relative to the port for effecting ...

SETTING MECHANICAL BARRIERS IN A SINGLE RUN

An operation may require isolation of a wellbore using multiple barriers. A single-run multiple barrier system may be deployed in a wellbore to position a first barrier at a first depth and a second barrier at second depth above the first barrier in the wellbore during a single run of a wellbore tubular string. The first barrier is coupled to a first miming tool. A wellbore tubular string segment couples the first miming tool is coupled to the second barrier. The second barrier is coupled to a second running tool that couples to the wellbore tubular string. The second barrier is locked until the first barrier is independently set at the first depth to prevent the second barrier from being set until the second depth is reached. Setting both barriers in a single run increases efficiency in an operation including reducing costs and time for completion of the operation. 1. A method of setting a single-run multiple barrier system comprising:deploying a single-run multiple barrier system on a wellbore tubular string in a wellbore of a formation, wherein the single-run multiple barrier system comprises a deep set barrier system at a distal end of the wellbore tubular string and a shallow set barrier above the deep set barrier system;determining if a first depth in the wellbore has been reached by the single-run multiple barrier system;setting a first isolation device of the deep set barrier system, wherein the shallow set barrier system comprises a rupture disk that prevents a lug from moving within a continuous j-slot to prevent setting of the shallow set barrier system during setting of the first isolation device;disconnecting the deep set barrier system from the wellbore tubular string;retrieving the wellbore tubular string to a second depth;setting a second isolation device of the shallow set barrier system; anddisconnecting the shallow set barrier system from the wellbore tubular string.2. The method of claim 1 , wherein setting the second device comprises:rupturing ...

ROTATING STINGER VALVE FOR J-SLOT CONNECTOR

A petroleum well toolstring valve includes a drill pipe string conveyed J-slot running tool for a top stinger on a retrievable bridge plug. The J-slot running tool includes a J-slot sleeve with J-slots for disconnectably receiving the stinger. The top stinger includes a cylindrical stinger portion with J-slot connecting lugs. An internal plug is arranged between a central connector and stinger bores. A cylindrical neck on the stinger portion spans the internal plug in the axial direction. The cylindrical neck, when covered by the J-slot sleeve, forms an annular flow space connecting upper and lower radial ports and thus central bores. The stinger portion has a rotatable sleeve valve body arranged on a stinger valve stem portion. The sleeve valve body has a sleeve valve port arranged for being aligned with the lower stinger port when rotated into an open position. The rotatable sleeve valve body is connected to the lugs for being rotated by the drill pipe string for opening or closing the valve. 1. A petroleum well toolstring valve comprising a drill pipe string-conveyed J-slot running tool for a top stinger on a retrievable bridge plug , both having a central connector and stinger bores , said J-slot running tool having:a J-slot sleeve with J-slots for disconnectably receiving said stinger with lugs of said top stinger,said top stinger having a cylindrical stinger portion with J-slot connecting lugs,wherein an internal plug is arranged between said connector and stinger bores, a cylindrical neck on said stinger portion spanning said internal plug in the axial direction, with an upper radial port into said central connector bore, and a lower radial port into said stinger central bore,wherein said cylindrical neck, when covered by said J-slot sleeve, forms an annular flow space, fluid connecting said upper and lower radial ports and thus said central bores,wherein said stinger portion having has a rotatable sleeve valve body arranged on a cylindrical inner, static, ...

Assembly and Method for Performing Aligned Operation with Tool Oriented in Downhole Tubular

To perform an aligned operation downhole, a tubular disposed downhole has an internal bore with a first inner circumference and has a target at a first radial orientation. A locator profile is defined about the internal bore at a first location, and an internal nipple is defined about the internal bore at a second location. The internal nipple has a second inner circumference less than the first of the internal bore. An orientation slot is defined longitudinally across the internal nipple and is disposed at a second radial orientation configured relative to the first radial orientation of the target. A tool is deployable into the internal bore. The tool has a locator to engage in the locator profile and has an orientation key to engage in the slot and align an operational component for the aligned operation with the target. 1. An assembly for performing an aligned operation downhole , the assembly comprising:a tubular for downhole defining an internal bore with a first inner radius, the tubular having a target at a first radial orientation, the internal bore defining a locator profile thereabout at a first location and defining an internal nipple thereabout at a second location, the internal nipple having a second inner radius less than the first inner radius of the internal bore, the internal nipple at least partially defining an orientation slot longitudinally therethrough and disposed at a second radial orientation configured relative to the first radial orientation of the target; anda tool deployable in a longitudinal direction into the internal bore of the tubular and having first and second portions, the first portion having a locator biased outward to engage in the locator profile of the tubular, the second portion rotatable relative to the first portion and having an operational component to perform the aligned operation at the first radial orientation of the target, the second portion having an orientor biased outward to engage in the orientation slot of ...

DOWNHOLE VALVE ASSEMBLY AND METHOD OF USING SAME

Actuatable valve tool including a tubular housing forming an axial flowbore. A slidable flow tube disposed within the housing and a shear sleeve disposed around at least a portion of the slidable flow tube. One or more valves disposed within the housing, each having an open position and a closed position. In the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough. The slidable flow tube moveable within the housing to transition the one or more valves between the closed position and the open position. 1. An actuatable valve tool comprising:a tubular housing having an axial flowbore;a slidable flow tube disposed within the housing and having the axial flowbore therethrough;a shear sleeve disposed around at least a portion of the slidable flow tube;one or more valves disposed within the housing, each having an open position and a closed position;wherein in the open position the one or more valves permit fluid flow within the axial flowbore, and in the closed position the one or more valves block fluid flow therethrough;wherein the slidable flow tube is moveable within the housing to transition the one or more valves between the closed position and the open position.2. The actuatable valve tool of claim 1 , wherein the slidable flow tube is moveable from a first position to a second position by a pressure differential claim 1 , in the first position the one or more valves are in the closed position and in the second position the one or more valves are in the open position claim 1 , thereby allowing fluid flow in a first direction.3. The actuatable valve tool of claim 2 , wherein the pressure differential is formed between the axial flowbore and an annulus between the tubular housing and the slidable flow tube.4. The actuatable valve tool of claim 2 , wherein the slidable flow tube is moveable to a third position claim 2 , the third position having the slidable ...

DOWNHOLE TOOL

The invention provides a downhole initiator tool () for use in initiating a downhole operation, and a method of use. The downhole initiator tool comprises a mandrel (), an initiator assembly (), and an anchor assembly () mounted on the mandrel. The anchor assembly comprises a radially extendable anchor member () for engaging an outer bore structure. The anchor assembly and the mandrel are axially moveable relative to each other in a first axial direction to sequentially extend the anchor member and activate the initiator assembly. 1. A downhole initiator tool for use in initiating a downhole operation , comprising:a mandrel;an initiator assembly; andan anchor assembly mounted on the mandrel and comprising a radially extendable anchor member for engaging an outer bore structure,wherein the anchor assembly and the mandrel are axially moveable relative to each other in a first axial direction to sequentially extend the anchor member and activate the initiator assembly.2. (canceled)3. (canceled)4. The downhole initiator tool according to claim 1 , wherein the creation of an anchor by the anchor member defines a limit or the end of a first movement action.5. The downhole initiator tool according to claim 1 , wherein anchor assembly and the mandrel are axially moveable relative to each other in the first axial direction in a first relative movement action to cause the anchor member to be extended claim 1 , and wherein the anchor assembly and the mandrel are axially moveable relative to each other in the same first axial direction in a second relative movement action to cause activation of the initiator assembly.6. (canceled)7. (canceled)8. (canceled)9. (canceled)10. The downhole initiator tool according to claim 4 , wherein the anchor member is retracted or be permitted to be retracted during the second movement action.11. The downhole initiator tool according to claim 1 , wherein the anchor assembly and the mandrel are axially moveable relative to each other in the first ...

Flow control mechanism for downhole tool

Flow control mechanism ( 100 ) for a downhole tool includes a housing ( 102 ), an inner liner ( 104 ), and a rotatable sleeve ( 106 ). The inner liner ( 104 ) is provided in and remains stationary relative the housing ( 102 ). The rotatable sleeve ( 106 ) can be arranged to rotate about the inner liner ( 104 ) to provide a closed configuration ( 900 ), a first open configuration ( 1400 ), and a second open configuration ( 1900 ). The closed configuration ( 900 ) can enable through-flow of fluid through the flow control mechanism ( 100 ) to a distal tool ( 50 ). The first open configuration ( 1400 ) can enable partial through-flow of fluid through the flow control mechanism ( 100 ) to the distal tool ( 50 ) and partial through-flow of fluid in a substantially radial direction. The second open configuration ( 1900 ) can prevent through-flow of fluid through the flow control mechanism to the distal tool ( 50 ) and to enable through-flow of fluid in a substantially radial direction.

DEFLECTOR ASSEMBLY AND EFFICIENT METHOD FOR MULTI-STAGE FRACTURING A MULTILATERAL WELL USING THE SAME

Provided, in one aspect, is a deflector assembly. The deflector assembly, in one embodiment, includes a deflector body having a deflector window located therein, and a deflector ramp positioned at least partially across the deflector window, the deflector ramp configured to move between first ({circle around (1)}), second ({circle around (2)}) and third ({circle around (3)}) different positions when a downhole tool moves back and forth within the deflector body. 1. A deflector assembly , comprising:a deflector body having a deflector window located therein; anda deflector ramp positioned at least partially across the deflector window, the deflector ramp configured to move between first ({circle around (1)}), second ({circle around (2)}) and third ({circle around (3)}) different positions when a downhole tool moves back and forth within the deflector body.2. The deflector assembly as recited in claim 1 , further including an actuation member positioned within the deflector body claim 1 , the actuation member configured to move the deflector ramp between the first ({circle around (1)}) claim 1 , second ({circle around (2)}) and third ({circle around (3)}) different positions.3. The deflector assembly as recited in claim 2 , wherein the actuation member includes an inner sleeve configured to engage with the deflector ramp at a downhole end thereof claim 2 , the inner sleeve configured to move the deflector ramp between the first ({circle around (1)}) claim 2 , second ({circle around (2)}) and third ({circle around (3)}) different positions.4. The deflector assembly as recited in claim 3 , wherein the inner sleeve includes a slot therein for following a cycle ring rotationally coupled to the deflector body.5. The deflector assembly as recited in claim 4 , wherein the slot is a J-slot that allows the inner sleeve to translate but not rotate relative to the deflector body.6. The deflector assembly as recited in claim 3 , further including an inner sleeve spring positioned ...

STRADDLE PACKER WITH FLUID PRESSURE PACKER SET AND AUTOMATIC STAY-SET

A straddle packer has a floating auto-J sleeve that automatically shifts the straddle packer from a run-in condition to a stay-set condition after pumping of high-pressure fluid into the straddle packer in excess of a predetermined pump rate is terminated. In the stay set condition, packer elements of the straddle packer remain in sealing contact with a well casing or well bore into which the straddle packer has been run. 1. A straddle packer with fluid pressure packer set and automatic stay-set , comprising:a floating auto-J sleeve that rotates freely on a piston mandrel of a modular pressure cylinder of the straddle packer, the floating auto-J sleeve including a continuous auto-J groove in an outer periphery thereof, the auto-J groove including a plurality of auto-J groove run-in slots and a plurality of auto-J groove stay-set slots; anda plurality of auto-J pins installed in a piston sleeve of the modular pressure cylinder, the piston sleeve reciprocating with respect to the piston mandrel in response to fluid pressure pumped into the straddle packer, and the plurality of auto-J pins being respectively received in and sliding within the continuous auto-J groove as the piston sleeve reciprocates with respect to the piston mandrel and the auto-J sleeve rotates on the piston mandrel.2. The straddle packer as claimed in wherein the auto-J sleeve is restrained from axial movement on the piston mandrel by an auto-J sleeve uphole end that abuts a piston connected to the piston mandrel and an auto-J sleeve downhole end that abuts a lower packer element compression bell connected to the piston mandrel.3. The straddle packer as claimed in wherein when the auto-J pins are in the auto-J run-in slots claim 1 , first and second packer elements of the straddle packer are in a relaxed condition that permits the straddle packer to be moved within a well casing or a well bore.4. The straddle packer as claimed in further comprising a plurality of auto-J groove pressure-set slots in ...

TOP-DOWN FRACTURING SYSTEM

A valve for use in a wellbore includes a housing including a housing port, a slidable closure member disposed in a bore of the housing and including a closure member port, and a seal disposed in the housing, wherein the closure member includes a first position in the housing where fluid communication is provided between the closure member port and the housing port, and a second position axially spaced from the first position where fluid communication between the closure member port and the housing port is restricted, wherein, in response to sealing of the bore of the housing by an obturating member sealingly engaging the seal, the closure member is configured to actuate from the first position to the second position. 1. A flow transported obturating tool for actuating a valve in a wellbore , comprising:a housing comprising a first engagement member and a second engagement member, wherein the first and second engagement members each comprise an unlocked and a locked position; anda core disposed in the housing, wherein the core is configured to actuate both the first engagement member and the second engagement member between the unlocked and locked positions;wherein, when the first engagement member is in the locked position, the first engagement member is configured to locate the obturating tool at a predetermined axial position in the valve;wherein, when the second engagement member is in the locked position, the second engagement member is configured to shift the valve from an open position to a closed position.2. The flow transported obturating tool of claim 1 , further comprising:a seal disposed in the outer surface of the core and in sealing engagement with an inner surface of the housing;wherein, in response to the application of a fluid pressure to a first end of the core, the core is configured to actuate both the first engagement member and the second engagement member between the unlocked and locked positions.3. The flow transported obturating tool of claim ...

Multi-Pressure Toe Valve

A toe valve having an outer tubular member, including at least one outer flow port, and an inner tubular member positioned at least partially within the outer tubular member and including a central flow passage. An indexing mechanism is positioned within the outer tubular member and there is a flow path allowing fluid pressure from the central passage to act against a first side of the indexing mechanism. A biasing device acts on a second side of the indexing mechanism and the indexing mechanism is configured to allow communication between the central flow passage and the outer flow port after the indexing mechanism is subject to a plurality of pressure cycles within the central flow passage.

TANDEM RELEASABLE BRIDGE PLUG SYSTEM AND METHOD FOR SETTING SUCH TANDEM RELEASABLE PLUGS

A method of setting a tandem releasable bridge plug system in a casing includes assembling a tandem bridge plug string including a lower bridge plug and an upper bridge plug. Both the upper bridge plug and the upper connector are initially disabled by a lock and unlockable from topsides; running in the tandem plug string on a drill pipe string until the lower plug is at its setting target depth in the casing; setting and shutting the lower plug; disconnecting the upper plug from the lower plug; pulling up the upper plug to its upper setting target depth in the casing, enabling the upper plug by releasing the lock; venting annulus gas to a central bore of the upper plug through a radial aperture below a packer of the upper plug and below a ball valve; shutting said ball valve in said central bore the upper plug; and disconnecting the drill pipe string from the upper plug. 1. A method of setting a tandem releasable bridge plug system in a casing comprising the steps of: a lower bridge plug with mandrel with a through-bore having a main bore ball valve and arranged on a lower, disconnectable connector; and', 'an upper bridge plug with a through-bore having a main bore ball valve and arranged on an upper, disconnectable connector, said upper bridge plug and said connector being initially disabled by a lock and being unlockable from topsides thereof, wherein disabling of said upper bridge plug is initially made by a ball seat axial sleeve arranged in a collet sleeve constituting said lock of said connector, said ball seat axial sleeve being releasable by a drop ball to allow said collet sleeve to be forced upwardly and unlock said lock enabling said upper connector to be axially and rotationally operable relative to the upper plug by the drill pipe string;, 'assembling a tandem bridge plug string comprising from bottom to toprunning in said tandem plug string on a drill pipe string until said lower plug is at a setting target depth thereof in the casing;setting said ...

Method and Apparatus for Injecting Fluid into Spaced Injection Zones in an Oil/Gas Well

An injection sleeve and apparatus for injecting fluid into a well includes a flow tube having a piston which upon fluid flow opens one or more outlet ports. The injection sleeve is adapted to include a variable orifice insert which prevents flow through the tool at a first selected pressure level until the outlet ports are in an open position, thereby protecting packing seals on either side of the outlet ports from undue wear and tear, and prolonging the life of the tool. At a second pressure level, the variable orifice insert permits flow through injection sleeve to the formation injection zones. A plurality of the sleeves may be used for sequentially injecting fluid into a plurality of injection formation zones surrounding a well. When injection fluid flow is terminated, the injection sleeves act as a dual barrier valve for preventing flow from the injection formation zones back to the well head. 1. An injection sleeve comprising;a) an outer housing having one or more outlet ports,b) an axially movable flow tube positioned within the outer housing have one or more outlets adapted to register with the one or more outlet ports,c) the axially movable flow tube including a piston portion,d) a power spring positioned between the outer housing and the axially movable flow tube, said power spring being compressed by axial movement of the flow tube in response to fluid flow within the injection sleeve, ande) a variable orifice insert positioned within the injection sleeve, the variable orifice insert having a valve to regulate the flow through the variable orifice insert.2. The injection sleeve as claimed in further including a pair of annular packing seals on either side of the outlets ports.3. The injection sleeve as claimed in wherein the piston portion includes an annular ridge claim 1 , and a pair of annular seals positioned on either side of the annular ridge.4. The injection sleeve of wherein the pair of packing seals are in sliding contact with the flow tube.5. ...

DOWNHOLE TOOL ASSEMBLY

A method of latching a production tubing to a packer in a wellbore, an assembly, and a connection, of which the method includes lowering the production tubing into the wellbore, the production tubing being coupled to a first body comprising a slot and a blocking member. The production tubing is lowered until a lug on a second body contacts the blocking member, the second body being coupled to a packer. The method includes raising the production tubing relative to the packer which causes the lug to move out of contact with the blocking member, lowering the production tubing into the wellbore again until the lug contacts and removes the blocking member, and rotating the production tubing such that the lug advances into the slot, so as to latch the production tubing and the packer together. 1. A method of latching a production tubing to a packer in a wellbore , the method comprising:lowering the production tubing into the wellbore, the production tubing being coupled to a first body comprising a slot and a blocking member, wherein the production tubing is lowered until a lug on a second body contacts the blocking member, the second body being coupled to a packer;raising the production tubing relative to the packer which causes the lug to move out of contact with the blocking member;lowering the production tubing into the wellbore again until the lug contacts and removes the blocking member; androtating the production tubing such that the lug advances into the slot, so as to latch the production tubing and the packer together.2. The method of claim 1 , wherein the blocking member is configured to block movement of the lug in the slot until the production tubing is to be latched to the packer.3. The method of claim 1 , wherein raising the production tubing relative to the packer comprises raising the production tubing without rotating the production tubing.4. The method of claim 3 , wherein the slot in the production tubing is at least partially helical.5. The method of ...

Milling and whipstock assembly with flow diversion component

An apparatus for performing a milling operation includes a mill having an internal fluid conduit and a fluid port configured to connect the internal fluid conduit to an exterior of the mill. A moveable flow diversion component is configured to move axially in the internal conduit from a first axial position in which fluid is prevented from flowing between the internal fluid conduit and the fluid port, to a second axial position in which the internal fluid conduit is in fluid communication with the fluid port. The apparatus also includes one or more slots configured to engage one or more pins extending into the internal fluid conduit, the one or more slots defining a path that directs movement of the flow diversion component. The flow diversion component is configured to be moved from the first to the second axial position by changing fluid pressure in the internal fluid conduit.

DRILL STRING ELEMENT AND DETACHABLE DRIVING ELEMENT

An assembly of a drill string element adapted to be held by the drill pipe rams of a blowout preventer (BOP) to enable the drill string to be disconnected at the BOP and a detachable driving element is described. The drill string element comprises a housing portion defining a longitudinal bore along a longitudinal axis X-X of the housing portion. At least one recess is arranged in the longitudinal bore, said at least one said recess () being arranged to engage at least one lug of a detachable driving element arranged to be disposed in the longitudinal bore to rotationally lock the housing portion and detachable driving element together. 1. A drill string element adapted to be held by the drill pipe rams of a blowout preventer to enable the drill string to be disconnected at the blowout preventer , the drill string element comprising:a housing portion adapted to be engaged and held by the drill pipe rams of a blowout preventer, the housing portion defining a longitudinal bore along a longitudinal axis of the housing portion;at least one recess arranged in the longitudinal bore, said at least one recess arranged to engage at least one lug of a detachable driving element arranged to be disposed in the longitudinal bore to rotationally lock the housing portion and detachable driving element together;at least one first guide surface arranged in the longitudinal bore, said at least one first guide surface arranged to slidably engage with said at least one lug when said detachable driving element is advanced along said longitudinal axis in a first direction to cause said detachable driving element to rotate through a first angle relative to the housing portion about said longitudinal axis; andat least one second guide surface arranged in the longitudinal bore, said at least one second guide surface arranged to slidably engage with said at least one lug when said detachable driving element is retracted along said longitudinal axis in a second direction, opposite to said ...

Circulation subassembly

Circulation Subassembly The present invention relates to acirculation subassembly (circsub) for incorporation in a drill pipe. The circsub has a flow through condition in which the circsub allows fluid to flow through a bore of the circsub and does not allow fluid communication between the bore of the circsub and an annulus located outside the drill pipe, a partial bypass condition in which the circsub allows fluid to flow through the bore of the circsub and allows fluid communication between the bore of the circsub and the annulus, and a full bypass condition in which the circsub does not allow fluid to flow through the bore of the circsub and allows fluid communication between the bore of the circsub and the annulus. An actuator is provided to change the circsub between conditions under the control of a controller.

WELLBORE TOOL WITH PRESSURE ACTUATED INDEXING MECHANISM AND METHOD

Pressure activated counting/indexing mechanisms for hydraulic fracturing sleeves and related processes are provided. The hydraulic fracturing apparatuses can include a tubular body having a housing and a flow port, a movable inner sleeve within the tubular body slidable from a first position blocking the flow port and a second position exposing the flow port; an inner indexing mechanism capable of being moved through a plurality of positions and can include the inner sleeve having a counting track comprising a plurality of different grooves; and a counting mechanism that can include a circular ring and pin that can be axially and rotationally movable in the counting track; an actuating mechanism can rely on the auto jay counting mechanism to provide a mechanical signal to either allow an actuating member to pass through and not open the flow ports or be retained so pressure shifts the sleeve to open the flow ports. 1. An apparatus comprising:a tubular housing for connecting in-line with a completion string, the housing having an upper end and a lower end, a wall defining an inner bore and an outer surface, and a flow port through the wall of the tubular housing;an inner indexing mechanism disposed within the inner bore of the housing, the inner indexing mechanism comprising;an indexing sleeve having an outer diameter with a counting track disposed around the outer diameter;a counting mechanism, configured for being moved through a plurality of positions, the counting mechanism comprising a pin and a ring for being disposed concentrically around the indexing sleeve, wherein the pin is configured for tracing the counting track; anda biasing member configured to urge the counting mechanism to trace the counting track; andan actuating mechanism disposed within the indexing sleeve and configured to overcome the biasing member and move the counting mechanism through a plurality of positions, the actuating mechanism being configured to be activated by an accordingly sized ...

Wellbore actuators, treatment strings and methods

A wellbore tubing string assembly with at least one port for communicating fluid between its inner bore and its exterior, can be actuated to move from a port-closed position to a port-exposed position using a series of deformable plugs of the same outer diameter that are placed in the inner bore, and that can deform so as to be squeezed through the inner bore, responsive to an application of force against each of the plugs. The plugs have an interference fit as they engage with the assembly at the inner bore. As a plug is squeezed through the inner bore and out of the assembly, its passage through the assembly is registered. When the number of plugs that have been so registered exceeds a predetermined threshold, the next plug that squeezes through the inner bore will cause the assembly to be actuated to the port-exposed position. The use of plugs having such an interference fit reduces the number of moving parts required to construct the assembly, which makes it more reliable and durable.

Sliding Sleeve Having Indexing Mechanism and Expandable Sleeve

A downhole tool, such as a sliding sleeve, is operable with pressure applied against one of a plurality of plugs deployed in the tool. A sleeve can engage the deployed plugs and can move with the engagement. The sleeve extends in an absence of external support and releases the engaged plug. However, an indexing mechanism is operable between the sleeve and an insert in the tool. The indexing mechanism moves with the sleeve in response to the engagement with the deployed plugs and counts those engagements. In response to a predetermined count, the indexing mechanism forms the external support of the one deployed plug engaged in the sleeve and moves the insert with the pressure applied against the one deployed plug, which is engaged in the sleeve and supported by the indexing mechanism. For example, the insert can move open in the tool relative to a flow port communicating outside the tool. 1. A downhole tool being disposed on tubing and being operable with pressure applied against one of a plurality of plugs deployed in the tool , the tool comprising:an insert disposed in the tool and being movable from a first position toward a second position;a sleeve disposed in the tool, the sleeve being engageable with the deployed plugs and being movable with the engagement, the sleeve being expansive in an absence of external support and releasing the engaged plug in response to the expansion; andan indexing mechanism disposed in the tool and being operable between the sleeve and the insert, the indexing mechanism moving with the sleeve in response to the engagement with the deployed plugs and counting the engagements, the indexing mechanism in response to a predetermined count of the engagements forming the external support of the one deployed plug and moving the insert from the first position toward the second position with the pressure applied against the one deployed plug engaged in the sleeve and supported by the indexing mechanism.2. The tool of claim 1 , wherein the tool ...

DOWNHOLE TOOL ACTUATION SYSTEM HAVING INDEXING MECHANISM AND METHOD

A downhole tool actuation system including: a tubing having a longitudinal axis and a main flowbore supportive of tubing pressure; an indexing mechanism in fluidic communication with the main flowbore, the indexing mechanism configured to count N number of tubing pressure cycles; a port isolation device movable between a blocking condition and an actuation condition, the port isolation device in the blocking condition for N−1 cycles of the indexing mechanism, and movable to the actuation condition at the Nth cycle of the indexing mechanism; and, a chamber sealed from the main flowbore in the blocking condition of the port isolation device, the chamber exposed to the tubing pressure in the actuation condition of the port isolation device. The downhole tool actuation system is configured to actuate a downhole tool upon exposure of the chamber to tubing pressure. 1. A downhole tool actuation system comprising:a tubing having a longitudinal axis and a main flowbore supportive of tubing pressure;an indexing mechanism in fluidic communication with the main flowbore, the indexing mechanism configured to count N number of tubing pressure cycles;a port isolation device movable between a blocking condition and an actuation condition, the port isolation device in the blocking condition for N−1 cycles of the indexing mechanism, and movable to the actuation condition at the Nth cycle of the indexing mechanism; and,a chamber sealed from the main flowbore in the blocking condition of the port isolation device, the chamber exposed to the tubing pressure in the actuation condition of the port isolation device;wherein the downhole tool actuation system is configured to actuate a downhole tool upon exposure of the chamber to tubing pressure.2. The downhole tool actuation system of claim 1 , further comprising a hydrostatic piston and the downhole tool claim 1 , wherein the hydrostatic piston is moved longitudinally to actuate the downhole tool upon exposure of the chamber to tubing ...

Multi-Cycle Wellbore Clean-Out Tool

A clean-out tool and method of cleaning out a wellbore. The clean-out tool is placed at the end of a coiled tubing or other conveyance string. The clean-out tool comprises a tubular housing providing an elongated bore through which fluid flows. The tubular housing has back-jetting ports disposed at an upward angle therein. The clean-out tool is configured to operate in a back-jetting mode when the clean-out fluid is pumped into the tubular housing at a first flow rate. In this mode, a portion of clean-out fluid flows through the bore, up an annular region and then through the back jetting ports. The clean-out tool is further configured to operate in a fluid flow-through mode when the clean-out fluids are pumped into the bore of the tubular housing at a second flow rate. In this mode, all of the clean-out fluid flows through the clean-out tool. 1. A multi-cycle clean-out tool for controlling a direction of a clean-out fluid within a wellbore , the wellbore having been lined with a string of production casing , and the clean-out tool comprising:a tubular housing providing an elongated bore through which fluids may be injected, the tubular housing having one or more back jetting ports;a piston disposed at an upstream end of the housing, the piston forming a pressure shoulder and having at least one orifice configured to deliver clean-out fluid from a wellbore conveyance tubing to the elongated bore of the housing;a tubular mandrel slidably positioned within the housing, the mandrel having a proximal end connected to or acted upon by the piston, and an open distal end forming a plunger; anda seat disposed along the tubular housing below the distal end of the tubular mandrel, the seat being configured to receive the plunger when the piston and connected tubular mandrel slide from a raised position to a lowered position along the tubular housing, and the seat providing a central orifice for receiving the clean-out fluid;and wherein the clean-out tool is configured to ...

Apparatus for making multiple orientation measurements in a drill string

An apparatus for making orientation measurements in a drill string within a well bore comprising a tubular housing (22) adapted for insertion into the drill string and first (13) and second (15) measuring devices in the housing for measuring first and second orientation characteristics, respectively, of the drill string. A signal generator (23) is responsive to the two measuring devices to provide a signal which is representative of the orientation characteristics measured. The measuring devices are operated alternately so that the signal from the signal generator is alternately representative of the first and second orientation characteristics. The signal from the signal generator, when the latter is controlled by the first measuring device, is different from the signal when the latter is controlled by the second measuring device so that it is readily apparent which of the two measuring devices is reporting.

Intelligent flow control valve reverse choke position

A mechanical indexer for an intelligent flow control valve comprising a plurality of choke positions is provided. The indexer can cycle from a full closed position, to a full open position, to gradually decreasing choke sizes. The indexer can cycle from a full closed position, to a full open position, to gradually decreasing choke sizes alternating with the full open position. The indexer can cycle from a full closed position, to a full open position, to a full closed position, to a full open position, to gradually decreasing choke sizes alternating with a full open position. The indexer can cycle from a full closed position, to a full open position, to a full closed position, to a full open position, to gradually decreasing choke sizes.

Downhole apparatus

Compression bypass valve and method for control thereof (options)

FIELD: mining.SUBSTANCE: group of inventions refers to mining and can be applied in compression bypass valves. Compression bypass valve comprises a body of the main section. Body of the main section contains an opening of the main section. Body contains a sleeve for sealing rings. Sleeve for the O-rings contains a sleeve opening for the O-rings and O-rings installed on both sides of the sleeve hole for the O-rings. Sleeve for the sealing rings is configured to prevent rotation with respect to the body of the main section, and is also movable relative to the body of the main section between the open position of the sleeve for the sealing rings and the closed position of the sleeve for the sealing rings. Sleeve hole for the O-rings is aligned with the opening of the main section when the sleeve for the O-rings is in the open position of the sleeve for the O-rings, the opening of the sleeve for the sealing rings is hermetically sealed from the opening of the main section by means of O-rings, when the sleeve for the sealing rings is in the closed position of the sleeve for the O-rings.EFFECT: technical result is to increase the efficiency of the compression bypass valve.14 cl, 38 dwg РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2 667 952 C1 (51) МПК E21B 34/12 (2006.01) F16K 15/02 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ (52) СПК E21B 34/12 (2018.05); F16K 15/023 (2018.05) (21)(22) Заявка: 2017133285, 20.05.2015 (24) Дата начала отсчета срока действия патента: Дата регистрации: (73) Патентообладатель(и): ХАЛЛИБЕРТОН ЭНЕРДЖИ СЕРВИСЕЗ, ИНК. (US) 25.09.2018 (56) Список документов, цитированных в отчете о поиске: US 2009114289 A1, 07.05.2009. SU (45) Опубликовано: 25.09.2018 Бюл. № 27 1139828 A, 15.02.1985. RU 2204688 C2, 20.05.2003. RU 2531692 C2, 27.10.2014. US 5711386 A, 27.01.1998. US 2010186953 A1, 29.07.2010. (85) Дата начала рассмотрения заявки PCT на национальной фазе: 25.09.2017 (86) Заявка PCT: US 2015/031755 (20 ...

Method of drilling underground wells from casing

FIELD: drilling of directional wells, particularly, drilling of directional wellbore from central cased wellbore. SUBSTANCE: in realization of drilling of additional wells from main wellbore by means of template having at least two through channels located above template is orienting driver chuck with through channel, and provided between orienting driver chuck, casing and at last one channel in template is tight seal for fluid. EFFECT: higher reliability of joint of respective units in drilling of additional directional wells from main wellbore. 11 cl, 12 dwg 1 95309 1сС ПЧ Го (19) РОССИЙСКОЕ АГЕНТСТВО ПО ПАТЕНТАМ И ТОВАРНЫМ ЗНАКАМ ВИ "” 2 150 567. (51) МПК? 13) Сл Е 21 В 7/06 12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ РОССИЙСКОЙ ФЕДЕРАЦИИ (21), (22) Заявка: 98109950/03, 05.09.1996 (24) Дата начала действия патента: 05.09.1996 (30) Приоритет: 26.10.1995 Ш$ 08/548,565 (46) Дата публикации: 10.06.2000 (56) Ссылки: МО 94105892 АЛ, 17.03.1994. $Ц 767ЗЗТА, 10.10.1980. $Ц 1798466 АЛ, 28.02.1993. 4$ 4068129 А, 17.01.1978. $ 43960175 А, 02.08.1983. 4$ 4415205 А, 15.11.1983. 4$ 4444216 А, 24.04.1984. Ц$ 4573541 А, 04.03.1986. ММО 95/117580 АЛ, 29.06.1995. (85) Дата перевода заявки РСТ на национальную фазу: 26.05.1998 (86) Заявка РСТ: 1$ 96/14066 (05.09.1996) (87) Публикация РСТ: М/О 97/15747 (01.05.1997) (98) Адрес для переписки: 117333, Москва, Ленинский пр-т 60/2, кв.160, Зылю В.П. (71) Заявитель: Маратон Ойл Компани (ЦЗ) (72) Изобретатель: Коллинз Гари Ж (Ц$), Трахан Кевин О (1$), Бауф Джон Л (4$) (73) Патентообладатель: Маратон Ойл Компани (ЦЗ) (54) СПОСОБ БУРЕНИЯ ПОДЗЕМНЫХ СКВАЖИН ИЗ ОБСАДНОЙ ТРУБЫ (57) Реферат: Изобретение относится к области бурения направленных скважин, в частности к бурению дополнительных наклонных стволов из центрального ствола, закрепленного обсадной трубой. Сущность изобретения: при реализации бурения дополнительных скважин из основного ствола посредством опорной плиты, имеющей по меньшей мере два сквозных канала, над плитой размещают ориентирующий ...

Controlled rotor tool

FIELD: gas and oil production. ^ SUBSTANCE: here is disclosed controlled rotor tool installed in downhole drilling device for correction of drilling direction. Also, the controlled rotor tool consists of a tubular external case, and of at least one controlled pusher movably secured on the case. The pusher travels between an extended position, whereat the controlled pusher touches a well wall formed with the drilling device, and a retracted position, whereat the controlled pusher does not contact the wall of the well. Further, the controlled rotor tool consists of a tubular shaft mounted inside the case and connected to a drill string on its first and second ends. The shaft transfers torque to a bore bit and also forms a channel for flow of drill agent to the bore bit. The controlled rotor tool comprises a pressure chamber formed between the shaft and the case and connected at least with one of the above said controlled pusher to transfer the controlled pusher from the retracted position into the extended one, and a piston movably installed in the tubular shaft. By means of preliminary specified changes of drilling agent pressure, the piston travels between the first axial position and the second axial position. In the first axial position internal section of the shaft is connected directly with the pressure chamber, which causes transfer of at least one above said controlled pusher into the extended position for contact with the wall of the well and corrects the direction of the drilling device. In the second axial position the internal section of the shaft is not connected directly with the pressure chamber to prevent transfer of one or each said controlled pusher into the extended position. ^ EFFECT: reliable operation of device at high pressure of drilling agent. ^ 27 cl, 15 dwg РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) 2 435 015 (13) C2 (51) МПК E21B 7/06 (2006.01) E21B 44/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ, ПАТЕНТАМ И ТОВАРНЫМ ЗНАКАМ (12) ...

Methods of treating subterranean formations using low-molecular-weight fluids

The present invention relates to systems and methods useful in subterranean treatment operations. More particularly, the present invention relates to systems and methods for treating subterranean formations using low-molecular-weight fluids. Examples of methods of the present invention include methods of treating a subterranean formation intersected by a wellbore; methods of enhancing production from multiple subterranean formations penetrated by a well bore during a single trip through the well bore; methods of enhancing production, in real time, from multiple subterranean formations penetrated by a well bore during a single trip through the well bore; and methods of reducing the cost of enhancing production from multiple formations penetrated by a well bore by stimulating multiple formations, on a single trip through the well bore, with a fluid that minimizes damage to the formation.

Well treating system with pressure readout at surface and method

A well treating tool string run on coiled tubing and having packers to isolate a zone to be treated in response to operation of a selector valve, pressure and temperature transducers in the tool string and a telemetry system which samples the measurements made by the transducers, an electrical conductor cable extending from the telemetry system up to the surface through the coiled tubing and to the inner end thereof on its storage reel, and a surface telemetry, data processing and display system that sends and receives encoded signals to and from the downhole telemetry system from which temperature and pressure values can be read out on the surface display in real time as the treating operation proceeds.

Hydraulic actuation of a downhole tool assembly

A DOWNHOLE TOOL ASSEMBLY (300) IS CONFIGURED FOR REPEATED AND SELECTIVE HYDRAULIC ACTUATION AND DEACTUATION. A PISTON ASSEMBLY (400) IS CONFIGURED TO RECIPROCATE AXIALLY IN A DOWNHOLE TOOL BODY (310). THE PISTON ASSEMBLY (400) RECIPROCATES BETWEEN A FIRST AXIAL POSITION AND SECOND AND THIRD AXIAL POSITIONS THAT AXIALLY OPPOSE THE FIRST POSITION. THE DOWNHOLE TOOL IS ACTUATED WHEN THE PISTON ASSEMBLY (400) IS IN THE THIRD AXIAL POSITION AND DEACTUATED WHEN THE PISTON ASSEMBLY (400) IS IN EITHER OF THE FIRST OR SECOND AXIAL POSITIONS. A SPRING MEMBER (352) BIASES THE PISTON ASSEMBLY (400) TOWARDS THE FIRST AXIAL POSITION WHILE DRILLING FLUID PRESSURE IN THE TOOL BODY URGES THE PISTON ASSEMBLY (400) TOWARDS THE SECOND AND THIRD AXIAL POSITIONS. DOWNHOLE TOOL ACTUATION AND DEACTUATION MAY BE CONTROLLED FROM THE SURFACE, FOR EXAMPLE, VIA CYCLING THE DRILLING FLUID FLOW RATE. FIG.16

Temporary plug system

A method and apparatus for establishing a fluid plug within a well bore which can then be substantially destroyed upon demand to permit reestablishment of the well within a short period of time thereafter. Increased pressure actuates a plug rupture mechanism which destroys the integrity of the plug and allows the plug to be substantially eliminated from the wellbore within a short period of time thereafter. In described preferred embodiments, the plug is comprised of a salt and sand mixture which is highly resistant to fluid compressive forces but is subject to destruction under shear tension forces. The plug may be encased within a plug sleeve which is, in turn, encased within a plug housing which may be disposed within the well bore. The sleeve is associated within the housing so that fluid may be displaced about the plug sleeve as the housing is disposed into the well bore. When the plug has reached the proper position within the well bore, the plug sleeve may be set within the housing such that fluid flow is stopped. A shear member is contained within the plug sleeve and detachably connected thereto. When required, the shear member may be released from the surrounding plug sleeve and forced against the plug to substantially destroy the integrity of the plug through introduction of shear tension forces within the plug structure and reestablish fluid flow through the housing. The plug is further dissolved into well bore fluids to substantially destroy it.

Well completions using casing valves

A well is completed by cementing a casing string in place in the well. A jetting tool assembly is run into the casing string on a tubing string. The jetting tool assembly engages a sliding sleeve of a casing valve and slides the sliding sleeve to an open position uncovering a plurality of housing ports in the casing valve housing in which the sleeve is received. Then, disintegratable plugs are hydraulically jetted from the housing ports to communicate a subsurface formation adjacent the casing valve with an interior of the casing string. Preferably, prior to opening the sleeve and hydraulically jetting the plugs, residual cement is drilled from the casing string, then further residual cement is hydraulically jetted from the casing valve, and then the casing valve is backwashed by reverse circulation.

Inflatable packer assembly

An inflatable packer assembly for use in a subterranean well bore to isolate an interval of the well bore and/or adjacent subterranean formation for treatment. The assembly comprises a hanger assembly, a fluid piston assembly and at least one inflatable packer. As constructed and positioned in the well bore, the hanger assembly and fluid piston assembly are sufficiently distant from the interval to be treated to inhibit being stuck in the well bore. By lowering and raising the tubing or drill string from which the inflatable packer assembly is suspended, the fluid piston assembly pumps well bore fluid into and from the packer to respectively inflate and deflate the packer. In this manner, the packer can be repeatedly inflated, deflated and repositioned within a well bore to treat successive intervals of the well bore.

Circulation sub with indexing mechanism

A downhole circulation sub or valve ( 105 ) includes a tubular housing with an outer port ( 140 ) and a valve piston ( 170 ) slidably disposed in the housing. A primary fluid flow path ( 130 ) extends through an inner flow bore of the housing and valve piston. In a first position, the valve piston isolates the outer port to prevent fluid communication between the inner flow bore and a well bore annulus. In a second position, the valve piston is moved to obstruct the inner flow bore and expose the outer port to the inner flow bore and allow fluid communication between the inner flow bore and the well bore annulus. An indexing mechanism ( 165 ) is coupled between the housing and the valve piston to guide the valve piston between the first and second positions. In some embodiments, the indexing mechanism includes a rotatable component ( 175 ).

HOLE TOOL BELOW, AND SYSTEM AND METHOD FOR CIRCULATING FLOW WITHIN A WELL HOLE

ferramenta de furo abaixo, e, sistema e método para circular fluido dentro de um furo de poço. sistema e método para circular fluido dentro de um furo de poço. uma junção de circulação configurada com elementos de comunicação sobre suas extremidades para ligar a junção a uma rede de comunicação de furo abaixo. um pistão deslizável na junção isola ou expõe uma fresta externa sobre a junção a um fluxo de fluido interno ao longo da rede de comunicação. métodos para ativar a junção de circulação via sinais transmitidos ao longo da rede de comunicação de furo abaixo. hole tool below, and system and method for circulating fluid within a wellbore. system and method for circulating fluid within a wellbore. a circulation junction configured with communication elements on its ends to connect the junction to a hole communication network below. A sliding piston at the junction isolates or exposes an outer crack over the junction to an internal fluid flow along the communication network. methods for activating the circulation junction via signals transmitted along the hole communication network below.

Inflatable packer assembly

Multi-Position Valve for Fracturing and Sand Control and Associated Completion Methods

A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular. Alternatively, the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order.