СПОСОБ КОНСЕРВАЦИИ, ЗАКАНЧИВАНИЯ И РЕМОНТА СКВАЖИНЫ

FIELD: oils and gas production. SUBSTANCE: group of inventions refers to methods and facilities for conservation, completion and repair of wells. The inventions facilitate control over the well during the said operations by means of assembling system of two partitions in well. Each of the partitions is located below the lower end of a flow string for well completion, when this string is installed into the well. As none of these partitions is installed higher in the borehole of the well, so both partitions rest in place during operations of conservation, completion and repair, which eliminates necessity to use a block of blowout preventers to facilitate reliable control over the well. EFFECT: reduced cost of well construction due to reduced time required for operation of drilling rig. 44 cl, 23 dwg РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) 2 362 005 (13) C2 (51) МПК E21B 33/12 (2006.01) E21B 33/035 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ, ПАТЕНТАМ И ТОВАРНЫМ ЗНАКАМ (12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ (30) Конвенционный приоритет: 08.08.2003 AU 2003904183 (73) Патентообладатель(и): ВУДСАЙД ЭНЕРДЖИ ЛТД (AU) (43) Дата публикации заявки: 20.09.2007 (45) Опубликовано: 20.07.2009 Бюл. № 20 2 3 6 2 0 0 5 R U (86) Заявка PCT: AU 2004/001055 (06.08.2004) (87) Публикация PCT: WO 2005/014971 (17.02.2005) C 2 C 2 (85) Дата перевода заявки PCT на национальную фазу: 09.03.2006 Адрес для переписки: 101000, Москва, М.Златоустинский пер., 10, кв.15, ЕВРОМАРКПАТ, пат.пов. И.А.Веселицкой, рег. № 11 (54) СПОСОБ КОНСЕРВАЦИИ, ЗАКАНЧИВАНИЯ И РЕМОНТА СКВАЖИНЫ ни одну из этих перегородок не размещают (57) Реферат: выше по стволу скважины, они обе могут Изобретение относится к способам и оставаться на месте во время операций по устройствам для консервации, заканчивания и консервации, заканчиванию и ремонту, что ремонта скважин. Обеспечивает возможность избавляет от необходимости использовать контроля над скважиной во время упомянутых блок противовыбросовых превенторов для ...

Пакер гидравлический автономный

Изобретение относится к оборудованию для нефтегазовой промышленности и может быть использовано для разобщения интервалов обсадной колонны при освоении и эксплуатации нефтяных, газовых и газоконденсатных скважин. Пакер гидравлический автономный содержит шток, установленную в верхней части штока присоединительную муфту, верхний и нижний уплотнительные элементы, между которыми установлен якорь, состоящий из верхнего и нижнего конусов, подвижно соединенных с кожухом, и подпружиненных плашек, втулку, соединенную с якорем через нижний конус при помощи срезных элементов, поршень, герметично установленный в корпусе. Корпус неподвижно и герметично установлен на штоке и образует с поршнем камеру, сообщающуюся с внутренней полостью штока через боковые отверстия. Втулка, соединенная с якорем через нижний конус при помощи срезных элементов, снизу соединена с поршнем, который выполнен с возможностью движения вверх при подаче жидкости под давлением во внутреннюю полость штока и передачи усилия цанге нижнего ...

MITTEL ZUR AKTIVIERUNG EINES WERKZEUGS IM BOHRLOCH

Interventionless method of setting a casing to casing annular packer

An annular packer 100 and method of use thereof comprising a solid mandrel 110 having first and second ends, a central bore 111 and an exterior, a first 130 and a second 170 sealing element, both connected to the exterior of the mandrel, wherein the second sealing element is expanded radially by axial movement of at least a portion of the second sealing element, a piston 140 movable from a first position to a second position within a chamber 145 on the exterior of the mandrel, the piston and the chamber being positioned between the first sealing element and the second sealing element, wherein a pressure differential exterior of the mandrel moves the first piston from the first position to the second position, the piston moving at least the portion of the sealing element. The annular packer may further comprise a rupture disc or other shearable or frangible device which is burst or broken upon exposure to a predetermined pressure.

WELL PACKER

... 1368691 Wells &c DRESSER INDUSTRIES INC 3 May 1972 [24 May 1971] 20605/72 Heading ElF A packer comprises a support 1, 11, 31, 47, a packer body 25 carrying packing 25a, 25b, a cylinder 38, a tubular member 19, pistons 28, 39 between the support and the cylinder forming a chamber A filled with fluid, a passage 34a from the chamber through the support, means 34 for closing the passage, and means 32 moved by a tool (not shown) to break the means 34 to connect the chamber to the interior of the support. Prior to running the packer into the well the chamber A is filled with liquid, the piston 28 being fixed during filling. The packer is attached to tubing and lowered to the desired level, changes in the temperature or pressure differential between the exterior of the packer and the chamber being compensated for by expansion or contraction of the liquid in the chamber. A setting tool (not shown) moves the sleeve 32 upwardly to shear the plug 34 and place ports 32c opposite the plug passage 34a ...

Multi-purpose fill and circulate well tool

Method and apparatus for a wellbore assembly

Packer

RETRIEVABLE WELL PACKER

METHOD AND APPARATUS FOR COMPLETION OF A WELL

RETRIEVABLE WHIPSTOCK

Retrievable well packer

Interventionless method of setting a casing to casing annular packer

Method and apparatus for a wellbore assembly

HYDRAULICALLY OPERATED PERMANENT TYPE WELL PACKER ASSEMBLY

PACKER ARRANGEMENT

An arrangement for lowering into a well bore casing on an operating string to sealably engage a packer that is supported on a tubular member so that the packer can be set either by a combination of hydraulic or mechanical action or mechanical action alone or hydraulic action alone includes a packer supported by a tubular member. An outer tubular member extends from adjacent the other end of the packer and telescopically receives the tubular member and a release mechanism releasably connects the tubular member and the outer tubular member with the operating string. A lock arrangement locks the tubular member and the outer tubular member together against relative longitudinal movement and the lock arrangement is operable after the release mechanism is actuated to disconnect the tubular member from the operating string whereupon said outer tubular member may be moved relative to the tubular member to expand the packer into sealing engagement with the casing.

Multi-position tool for running and setting a packer

A packer is locked onto a service tool by separation shear pins during a run-in operation. The separation shear pins are decoupled with respect to run-in handling forces by a set of transfer support lugs. The transfer support lugs carry the weight of the packer and the hang weight of equipment supported by the packer so that no weight is applied to the shear pins during a run-in operation. The packer is set and its hang load is transferred to the separation shear pins after the packer is set by the application of hydraulic pressure against an annular piston carried on the service tool. The piston is locked during run-in by a group of transit shear pins. Movement of the annular piston shears the transit pins and unsupports a collet latch to permit retraction of the transfer support lugs and disengagement of the service tool mandrel from the packer. The service tool is then released from the packer by increasing hydraulic pressure or by pulling up on the work string, or both, and shearing ...

Retrievable well packer

Retrievable packer

Retrievable well packer

Apparatus and method for orienting and setting a hydraulically actuated tool in a borehole

An apparatus for detecting and properly orienting a hydraulically-actuatable tool in a borehole and commencing drilling in a single trip of the drill string includes an MWD subassembly, for sensing the orientation, and a bypass valve for setting the hydraulically-actuatable tool once it is properly oriented and for thereafter conducting the drilling fluid to the cutter assembly. The method of setting a hydraulically-actuatable tool and commencing drilling in a single trip of the drill string includes the steps of running the hydraulically-actuatable tool into the borehole on a drill string which includes an MWD subassembly, sensing the orientation using the MWD subassembly, orienting the drill string to the desired orientation, and setting the hydraulically-actuatable tool.

Resilient packer set at a pressure threshold

A packer 80 for use inside a casing (70, figure 4) of a subterranean well includes a resilient element 84, a housing 104 and a rupture disc 124. The resilient element is adapted to seal off the well annulus when compressed by the housing in response to pressure exerted by the annulus fluid on a piston head 119 of the housing. The housing includes a port 122 for establishing fluid communication with the annulus. The rupture disc prevents the fluid in the annulus from entering the port and contacting the piston head until the pressure exerted by the fluid exceeds a predetermined threshold and ruptures the disc. The packer may include a swab cup (figure 14) that allows the annulus above the packer to be pressurised. Once the packer is set, then in some embodiments the tubing can be moved with respect to the packer.

HYDRAULIC RETRIEVABLE PACKER

A hydraulic well packer for releasable setting within a well casing is disclosed. The packer includes a hydraulic actuator assembly mounted between annular packing seal elements and anchor slips, with the seal elements, hydraulic actuator assembly and anchor slips being mounted for sliding movement along the packer mandrel. Premature retraction of the setting cylinder relative to the piston is prevented by interlocking action of a shear screw lock and a transfer lug against the piston, setting cylinder and a tubular setting wedge. The piston is locked against the anchor slips and the slip housing so that seals mounted on the piston head which engage the mandrel and the setting cylinder cannot be dragged and worn out prematurely in response to hydraulic pressure fluctuations imposed after the packer has been set and sealed. The setting piston and setting cylinder are locked together during run-in by the shear screw and by interlocking engagement of the transfer lug. The transfer lug is shifted ...

Inflatable tool with rib expansion support

Electrically operated well safety release joint

An electrically operated well annulus safety valve includes a housing having an inner through bore 170 and a passageway 172 connected to the well annulus above and below a packer (not shown), flow through the passageway 172 being controlled by a closure member 178 which is urged to a closed position engaging seat 180 by spring 182 and which can be moved to its open position by means of armature 184 and solenoid coil 188. The safety valve also includes an electrically operated equalising valve comprising a fixed ring with passage 190 and a movable ring 192 with passage 194. The ring 192 can be moved by electric motor 196 to bring the passages 190 and 192 into and out of alignment to open and close the equalising valve.

A solenoid operated blanking block valve

Multiple-completion packer and locking element therefor

Setting apparatus for hydraulic downhole tool

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

Mechanism for anchoring a well tool

Improvements in or relating to providing isolation between hydrocarbon producing zones in subterranean oil wells

A method of isolating production zones in a well comprising the steps: (a) running a retrievable packer assembly into the well, the retrievable packer assembly comprising an upper hydraulically set packer A with primary 30 and secondary strings 32 extending therefrom and a lower retrievable packer F; (b) locating a lower end of the secondary string 32 at a lower production zone and a lower end of the primary string 30 at an upper production zone; (c) setting the lower packer F to anchor and seal against an inner wall of a tubular in the well; (d) setting the upper packer A to anchor and seal against the inner wall of the tubular in the well; (e) producing the well; (f) running a tool and severing a tubular section in the upper packer A to unset the upper packer; (g) pulling the secondary string to unset the lower packer F and retrieve the packer assembly; characterised in that: the upper packer is set by applying pressure to the primary string 30; the lower packer is set by applying pressure ...

RETRIEVABLE WELL PACKER

Electrically controlled well circulating sleeve

A method and apparatus of electrically and sequentially completing an oil and/or gas well through a tubing production string in a well casing. The operation includes electrically and sequentially actuating downhole equipment such as well packers, a safety joint, well annulus safety valve, solenoid actuated tubing safety valve, blanking block valve, circulating sleeve, and receiving electrical feedback from the equipment determining the position of the downhole equipment.

Hydraulically actuated well packers

... 933,521. Wells. BAKER OIL TOOLS Inc. March 13, 1962 [March 30, 1961], No. 9631/62. Class 85. A well packer A comprises a body 10 carrying a resilient packing 33, actuating means 17, 31 engaging the upper part of the packing, actuating means 54, 45, 35 engaging the lower part of the packing, hydraulicallyoperated means 55, 59 on the sleeves 31, 54 of the actuating means responsive to the hydrostatic head of fluid in the well for shifting the actuating means relative to each other to force the packing into contact with casing B, means 67, 75 for preventing the head moving the actuating means, and means 78 for shifting the preventing means to an inoperative position. Figs. 1, 1a show the packer attached to tubing C, 15 and being run into the casing. The packer is set by dropping a ball 85 through tubing C and applying pressure so that a pin 84 is sheared and a valve 82 is moved to open ports 80, 81 in the body and the sleeve 31, the ball then falling to the bottom of the well. Well fluid entering ...

Method and apparatus for hybrid element casing packer for cased-hole applications

Well tool

Disclosed is a hydraulically operable well packer for releasable setting within a well conduit, including a seal assembly for sealing the packer to the conduit and an anchor assembly for anchoring the packer to the conduit. The seal assembly includes sealing members for engaging the conduit as well as secondary sealing members for engaging a central mandrel of the packer, both sets of sealing members being constructed of material which permits the mandrel to remain sealed to the well conduit in the presence of high temperatures. The packer may be released by straight longitudinal movement of the mandrel relative to the outer packer assembly.

Method and apparatus for a wellbore accumulator system assembly

Downhole measurement system and method

Hybrid-tieback seal assembly using method and system for interventionless hydraulic setting of equipment when performing subterranean operations

An interventionless hydraulic setting system includes first and second compensating volumes 312, 324 separated from respective first and second working volumes 316, 320 by hydraulic control devices 315, 336, and a delivery port 334 openable by a shifting sleeve 328. The shifting sleeve is operable in response to a pressure difference between the first and second working volumes. The second working volume is smaller than the first working volume. The delivery port delivers pressure to downhole equipment. The working fluid may be a compressible fluid such as silicone oil. Also claimed is a hybrid tieback seal assembly comprising an interventionless setting system as described above.

RETRIEVABLE WELL APPARATUS

RETRIEVABLE PACKER

Hydraulic set permanent packer with isolation of hydraulic actuator and built in redundancy

Activation of downhole tools

WELL COMPLETION APPARATUS AND METHODS

Improvements in or relating to well abandonment

Downhole apparatus

Open-hole pressure tight multilateral junction

Provided, in one aspect, is a well system and a method for forming a well system. The well system, in one aspect, includes a main wellbore, the main wellbore having a main wellbore open hole section, and a lateral wellbore extending from the main wellbore, the lateral wellbore having a lateral wellbore open hole section. The well system, according to this aspect, further includes a main bore completion located within the main wellbore and a lateral bore completion located within the lateral wellbore, and a multilateral junction positioned at an intersection between the main wellbore open hole section of the main wellbore and the lateral wellbore open hole section of the lateral wellbore, the multilateral junction including a main bore leg forming a first pressure tight seal with the main bore completion and a lateral bore leg forming a second pressure tight seal with the lateral bore completion such that the main bore completion and the lateral bore completion are hydraulically isolated ...

A method of suspending, completing and working over a well.

A method of suspending, completing and working over a well

Apparatus, and in particular obturator annular, intended to be introduced into a control to seal the annular space formed between this control and an element placed inside the aforementioned control.

Production fluid control device for oil/gas wells.

RELIEF VALVE FOR OIL BOREHOLES

PROCEDURE FOR ADJUSTING, FINISHING AND AUFWÄLTIGEN OF A BOREHOLE

Well plugging apparatus and method

Apparatus and method for hydraulically actuating a downhole device from a remote location

Stage tool

The present invention generally relates to a stage tool. In one aspect, a downhole tool for use in a wellbore is provided. The tool includes a body having a bore. The tool further includes a seal assembly attached to the body. The seal assembly having an expandable annular member, a seal member and an expander sleeve, wherein the seal member includes one or more anti-extrusion spring bands embedded within the seal member. The tool further includes a slip assembly attached to the body. The slip assembly includes slips that are configured to engage the wellbore.

INFLATABLE TOOL WITH RIB EXPANSION SUPPORT

Activating means for drilling apparatus

Production fluid control device for oil/gas wells

Multi-piston hydrostatic setting tool with locking feature and pressure balanced pistons

... [00023] A hydraulically actuated setting tool has a plurality of pistons that move in tandem when unlocked. The pistons are initially in pressure balance to take a load off a single locking mechanism that retains all the pistons. The pistons move due to admission of hydrostatic and/or applied pressure from the annulus on one side of each piston with an opposite side exposed to atmospheric pressure. The locking member is exposed to the annulus and is located away from any atmospheric chambers associated with the pistons. In this manner the components can be made thicker to resist burst and collapse pressure and the loads on the locking member reduced due to initial piston pressure balance configuration. Depths of greater than 8,000 meters can be used due to one or more of the described design features.

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Extreme service packer having slip actuated debris barrier

A subsurface well tool actuator

Hydrostatically actuated packer

HYDRAULICALLY SET WELL PACKER

METHOD AND APPARATUS FOR A WELLBORE ASSEMBLY

A method and apparatus for a wellbore assembly. The wellbore assembly may comprise a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline; an accumulator system connected to the conveyance member; and a setting tool connected to the accumulator system. The accumulator system may be configured to supply a fluid pressure to actuate the setting tool. A method of operating a wellbore tool may comprise lowering a wellbore assembly into a wellbore using a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline, wherein the wellbore assembly includes an accumulator system and a setting tool. The method may comprise actuating the accumulator system to provide a fluid pressure to the setting tool. The method may comprise actuating the setting tool using the fluid pressure.

RETRIEVABLE WELL PACKER

A retrievable travel packer includes a packer mandrel with an expandable packing element disposed about the mandrel. Upper and lower shoes are received about the mandrel above and below the expandable packing element for compressibly engaging the packing element. A slip assembly is received about the mandrel for anchoring the packer within the well bore. Upper and lower wedges are received about the mandrel above and below the slip assembly for wedging the slip assembly radially outward upon longitudinal compression of the packing element. The mandrel is nonrotatably connected to each of the upper and lower shoes and upper and lower wedges for preventing rotation of those components relative to the mandrel in the event the packer must be milled out of a well bore. The mandrel is initially releasably longitudinally locked relative to the lower wedge by a releasing collet attached to a lower end of the mandrel and having radially outward extending lugs received within a groove of the lower ...

RETRIEVABLE WELL BORE TUBULAR MEMBER PACKER ARRANGEMENT AND METHOD

RETRIEVABLE WELL BORE TUBULAR MEMBER PACKER ARRANGEMENT AND METHOD A retrievable packer arrangement that can be used as a permanent production packer employs a simple compression set packer (P) which can be either mechanically, hydraulically or wireline explosively set and retrieved by coupled or coiled pipe or wireline. The arrangement includes an adapter (A) supported by the setting tool (ST) which surrounds an external seal surface (19) on the upper end of an inner tubular member (I) which seal surface is exposed after the packer arrangement isset in a well bore tubular member (T) by release of the setting tool (ST) from the inner member (I) and removal of the adapter (A) therewith, so that a production string (PS) may then sealingly telescope over the inner member upper end. An outer member (O) includes release means adjacent its upper external end including an external grapple engaging surface means (100) so that the packer arrangement can be released without engaging the packer (P ...

SLACK ADJUSTMENT FOR SLIP SYSTEM IN DOWNHOLE WELL APPARATUS

BP-126-PA-US A well packer having a radially extendable and retractable resilient annular sealing element and slip assembly includes a slack adjusting mechanism for maintaining the cooperating slip cones and slip members in an axially adjusted position to reduce radial play in the slip members when the slip assembly is in the retracted condition. The slack adjusting mechanism includes an internal threaded sleeve threadedly engaged with an integral tubular portion of the upper slip cone. The sleeve is disposed between the slip assembly and the sealing element and includes an annular seal urging shoulder formed thereon.

PACKER

Packer includes a body member, and a metal ring is disposed in its entirety within an annular recess in the body member. The recess has opposed die surfaces; and a circumferential opening extending entirely around the peripheral outer surface of the body member. Hydraulic fluid is flowed through passage into the recess to apply pressure to the inner peripheral surface of the metal ring to expand the ring radially outwardly and force its outer peripheral surface through the circumferential opening and into annular sealing engagement with the opposed surface of the well casing.

FLOATING PISTON FOR SELECTIVE HYDRAULIC PACKER

SECONDARY LOCK FOR A DOWNHOLE TOOL

A downhole tool includes a mandrel, a sealing element disposed around the mandrel, an upper cone disposed above the sealing element and a lower cone disposed below the sealing element, an upper slip assembly disposed above the upper cone and a lower slip assembly disposed below the sealing element, at least one lock ring configured to maintain energization of the sealing element when the downhole tool is set, and a secondary lock that couple the upper cone with the at least one lock ring. A method of increasing pack-off force of a downhole tool includes setting the downhole tool and energizing further the sealing element by applying a differential pressure to the downhole tool. A method of retrofitting a downhole tool includes providing a secondary lock disposed around a mandrel, the secondary lock including at least one arm having an axial portion extending downwardly therefrom and a threaded portion, and assembling the secondary lock to the downhole tool, the assembling including engaging ...

ALTERNATIVE PACKER SETTING METHOD

Fluid setting pressure is delivered to a hydraulically set well packer through an external conduit (28) strapped to the exterior of a well workstring above the packer assembly (26). The continuity of the external conduit is continued past the packer assembly by following a flow channel along the mandrel sleeve (44) thickness. Representatively, the external conduit may serve a primary well function other than packer setting (e.g. well chemical delivery). A calibrated rupture element (68) in the external conduit is disposed to initially obstruct external conduit flow past the packer element. Consequently, fluid pressure transferred down the external conduit is first channeled to the packer setting pressure chamber. After setting, the fluid pressure in the external conduit is increased to rupture the calibrated element. When the external conduit flow channel is opened by rupture of the calibrated element, and the additional well service function may be accomplished.

METHODS AND SYSTEMS FOR MAINTAINING A PRESSURE DIFFERENTIAL BETWEEN PAIRS OF PACKERS

Examples of the present disclosure relate to systems and methods for fracturing systems that maintain a substantially constant pressure differential between a first pressure zone and a second pressure zone.

DOWNHOLE ACTUATION SYSTEM UTILIZING ELECTROACTIVE FLUIDS

Downhole wellbore tolls (14) are actuated by electrically controllable fluids energized by a magnetic field for example. When energized, the viscosity state of the fluid may be increased by a degree depending on the fluid formulation. Reduction of the controllable fluid viscosity by terminating a magnetic field acting upon the fluid may permit in situ wellbore pressure to display a tool actuating piston (16). Displacement of the tool actuating piston (16) is prevented by the controllable fluid in a viscous state. The viscous sate of the fluid is energized by a magnetic field environment. When the field is de- energized, the controllable fluid viscosity quickly falls thereby permitting the fluid to flow through an open orifice (40) into a low pressure receiving volume (36). In an alternative embodiment of the invention, an expandable volume fluid may be used against a slip actuating element in the same manner as a fluid pressure motor. A magnetic field, aligned to act upon the controllable ...

METHODS AND APPARATUS FOR A DOWNHOLE TOOL

An apparatus and method for operating a packer and a fracture valve is show n. The packer may include a tubular mandrel having a longitudinal bore with an annular packing element and a first piston disposed around the mandrel, wherein the first piston is operable to set the packing element, and a second piston operable to isolate fluid communication between the first piston and the mandrel bore. The fracture valve may include a tubular mandrel having a longitudinal bore and a port, a piston operable to close fluid communication between the bore and the port, and a latch dispose d between the piston and the mandrel operable to resist movement of the piston .

IMPROVED PACKER

A packer for a well is described. The packer comprises a seal element (12 ) and seal setting apparatus (14). The seal setting apparatus is moveable wi th respect to the seal element in a setting direction (X) to apply a setting force to the seal element to move the seal element from a run-in configurat ion to a set configuration in which, in use, the seal element forms a contac t seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction (X), will increase the setting force appli ed by the seal setting apparatus to the seal element to maintain the seal.

FRACTURING TOOL ANCHOR

The present invention is directed to a fracturing tool anchor adapted for use with a work string in a wellbore. In a preferred embodiment, the anchor has a housing with a central passage and an uphole and downhole end. The housing has a plurality of ports positioned circumferentially around the housing and along the length of the housing. The ports each contain an engagement member, such as a piston, and a return spring. The engagement member is adapted to extend radially outward when the anchor is pressure activated, to engage the wall of the casing or wellbore. The present application is also directed to a fracturing tool anchor that does not need to be pressure activated and utilizes slips as the engagement members.

TOOL WITH SETTING FORCE TRANSMISSION RELIEF DEVICE

A packer for a well is described. The packer comprises a seal element and seal setting apparatus. The seal setting apparatus is moveable with respect to the seal element in a setting direction to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which, in use, the seal element forms a contact seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction, will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

PACKER ASSEMBLY HAVING DUAL HYDROSTATIC PISTONS FOR REDUNDANT INTERVENTIONLESS SETTING

A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. A first activation assembly initially prevents movement of the first piston. A second activation assembly initially prevents movement of the second piston. A seal assembly is disposed about the packer mandrel between the first and second pistons such that actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly and actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly to radially expand the seal assembly.

PRESSURE ACTIVATED DOWN HOLE SYSTEMS AND METHODS

Systems and methods for activating a down hole tool in a wellbore. A piston is moveable from a first position to a second position for activating the down hole tool. The piston includes a first side exposed to an activation chamber, and a second side operatively coupled to the down hole tool. A rupture member has a first side exposed to the activation chamber and a second side exposed to the interior of a base pipe. The rupture member is configured to rupture when a pressure differential between the activation chamber and the interior reaches a predetermined threshold value, at which point the rupture member allows fluid communication between the interior and the activation chamber to pressurize the activation chamber and move the piston, thereby activating the down hole tool.

WHIPSTOCK APPARATUS AND METHODS OF USE

Retrievable Well Packer

METHOD AND APPARATUS FOR HYBRID ELEMENT CASING PACKER FOR CASED-HOLE APPLICATIONS

The present invention is directed to a new and improved wellbore packing device for use in isolating zones within a subterranean wellbore and to methods for applying the packing device in a cased-hole application. The present invention is directed to a new and improved inflatable or external casing packer (ECP) for us e in cased wellbores. A hybrid inflatable packing element design in an ECP is presen ted, having in a single-unit, anchoring and sealing sections for application in cased wellbores using a phase change inflation medium such as cement or epoxy or the l ike. The present invention overcomes limitations of existing prior art ECP's since th ese prior art ECP's are not capable of providing both sealing and anchoring packing elements in a single unitized design in size and access restricted wellbores. The inflatable elements comprise a sealing section that uses a noncontinuously reinforced elastomeric element with anti-extrusion ribs at its ends. When fille d with the inflation medium ...

PACKER FOR INSTALLATION OF GRAVEL FILTER WITH ALTERNATIVE FLOW CHANNEL AND METHOD FOR COMPLETION OF WELL BORE

Устройство и способ заканчивания ствола скважины, включающий в себя создание пакера, имеющего внутренний шпиндель, альтернативные каналы потока вдоль внутреннего шпинделя и уплотняющий элемент снаружи внутреннего шпинделя, включающий в себя соединение пакера с трубным изделием, затем спуск пакера и соединенного с ним трубного изделия в ствол скважины. В одном аспекте пакер и соединенное с ним трубное изделие можно устанавливать вдоль необсаженного участка ствола скважины. Трубное изделие может являться песчаным фильтром, причем песчаным фильтром, содержащим основную трубу, окружающую фильтрующее средство и альтернативные каналы потока. Способ включает в себя установку пакера и нагнетание гравийной суспензии в кольцевую зону, образованную между трубным изделием и окружающим стволом скважины, и затем дополнительное нагнетание гравийной суспензии через альтернативные каналы потока для обеспечения, по меньшей мере, частичного обхода гравийной суспензией уплотняющего элемента пакера. A device and method for completing a well bore, including creating a packer having an internal spindle, alternative flow channels along the internal spindle and a sealing element outside the internal spindle, including connecting the packer to the tubular, then lowering the packer and the tubular connected to it wells. In one aspect, the packer and its associated tubular may be installed along an uncased section of the wellbore. The tubular article may be a sand filter, with a sand filter containing a main pipe, surrounding filter media and alternative flow channels. The method involves installing a packer and injecting a gravel suspension into an annular zone formed between the tubular and the surrounding wellbore, and then further injecting the gravel suspension through alternative flow channels to provide at least a partial bypass of the packer packing element.

ANCHOR TOOL FOR HYDRO FRACTURING OF FORMATION

Gravity and hydraulic pressure combined type double-sealing packer

PROCEDE ET DISPOSITIF POUR INSTALLER DES GARNITURES D'ETANCHEITE DANS UN PUITS

A UN EQUIPEMENT A GARNITURES D'ETANCHEITE, IL EST ASSOCIE UN DISPOSITIF DE COMMANDE DESTINE A ETRE INSERE DANS LEDIT TRAIN DE TIGES EN DESSOUS OU AU-DESSUS DE L'EQUIPEMENT A GARNITURES D'ETANCHEITE. LE DISPOSITIF DE COMMANDE COMPREND DES MOYENS D'ACCUMULATION D'ENERGIE HYDRAULIQUE 150, 155, 14, UNE LIGNE HYDRAULIQUE 19 DE CONNEXION DE CES MOYENS D'ACCUMULATION AVEC DES MOYENS DE MISE EN COMPRESSION DES GARNITURES D'ETANCHEITE, ET DES MOYENS COMMANDABLES 166, 167, 168, 17 POUR MAINTENIR LADITE ENERGIE HYDRAULIQUE DANS LESDITS MOYENS D'ACCUMULATION ET ENSUITE POUR LIBERER LADITE ENERGIE DANS LADITE LIGNE HYDRAULIQUE. APPLICATION NOTAMMENT AUX TESTS DE PUITS AVANT PRODUCTION.

CONTROLLER OF FLOW FOR CASING

VALVE OF SAFETY HAS DIRECT INSTALLATION IN a TUBE OF PRODUCTION Of a PUITSPETROLIER AND PROCESS OF IMPLEMENTATION

THE PISTON LOCK THE WELL JUST ABOVE THE SOURCE TO PERMIT ITS CLEARING WITH PRESSURE (DRILLED WELL)

DILATABLE STOPPER Of OBTURATION OF the DRAINS

WELL PACKER AND TESTING APPARATUS

SLIDING SLEEVE ASSEMBLY FOR A HYDRAULICALLY SET WELL PACKER

Valve for hydraulic setting packer setting tool and method of setting a hydraulically settable packer therewith

A valve assembly is mounted with the setting tool for a hydraulically actuated well packer. The valve is located at a fluid passage in the setting tool and movable to control fluid flow from inside the setting tool to the well packer setting mechanism. In using this equipment, the valve is open when the setting tool is positioned within the well packer for setting of the well packer so fluid can pass through the setting tool and into the packer hydraulic setting mechanism. The valve is closed when the setting tool is removed from the well packer in order that fluid can flow through the setting tool and also through the bore of the well packer mandrel for fluid communication through the well tubing to a location below the packer without leakage into the annular cavity above or below the packer.

Gravel packing system

A gravel packing system in which the gravel screen and attached packer are anchorable in a well bore. A cross-over tool has an indicator device which cooperates with the gravel screen to provide surface indications of the downhole tool positions and the operation of a gravel valve. A setting tool can be used with the cross-over tool to set the packer and is releasable by hydraulic pressure. The setting tool and packer are releasably and co-rotatively coupled permitting right hand rotation while going in the well bore. The cross-over tool has a float valve which permits reverse circulation in low pressure wells. The packer has a release system for permitting retrieval of the packer.

Well plugging apparatus and method

An apparatus for plugging a burning or gushing well comprises a hollow tubular plug body (20) sized for insertion into a well casing (112). Provided on the plug body are a retainer module (54) for retaining the plug within the well casing; a sealing sleeve (46) provided for forming a seal between the plug body and the well casing; and a valve assembly (50) for selectively closing a hollow internal passageway of the tubular plug body. The plug body is loaded on a gantry assembly (21), which in turn is carried by a shielded vehicle (24). At the base of the gantry assembly are provided an alignment assembly (37) for aid in approach to the well casing and a cutter assembly (40) for sawing off inordinately protruding casings. In one embodiment, a protective break-away shell (118) circumferentially surrounds at least a portion of the plug body.

TUBING HANGER RELEASING AND RETRIEVING TOOL

A tool for releasing and retrieving a tubing hanger, and the like, anchored in a well casing disposed in a well bore, the tool being connectible to a running string for lowering into the well casing toward the tubing hanger and being oriented upon engaging the tubing hanger to a predetermined rotational position, latch means of the tool being coupled to the tubing hanger, enabling an upward pull to be taken on the running string and tool for application to the tubing hanger to effect its release from the well casing and its retrieval from the well casing.

HYDRAULIC WELL PACKER

A retrievable well packer for downhole operations, comprising an upper mandrel and a lower mandrel connected through a quick threaded connection, a hydraulic actuating assembly for downwardly moving under fluid pressure, a packing assembly for sealing against the well, first coupling mechanism between the upper mandrel and the hydraulic actuating assembly and second coupling mechanism between the lower mandrel and the hydraulic actuating assembly, with the second coupling mechanism connecting the lower mandrel and the hydraulic actuating assembly against rotation but permitting relative axial movement. 1. A retrievable well packer for downhole operations in a well casing of a wellbore , the packer comprising:{'b': 3', '17, 'a mandrel including an upper mandrel connected to a lower mandrel both connected to each other through a quick threaded connection,'}{'b': 4', '7', '7', '8', '11', '18', '3', '17', '37', '17, 'a hydraulic actuating assembly -, A, -, for downwardly moving over along the upper mandrel and the lower mandrel upon receiving fluid pressure in a hydraulic pressure chamber defined between the hydraulic actuating assembly and the lower mandrel ,'}at least one packing assembly for sealing against the casing upon downward movement of the hydraulic actuating assembly,{'b': 3', '7', '3', '4', '7', '7', '8', '11', '18, 'first coupling means A, A between the upper mandrel and the hydraulic actuating assembly -, A, -, , and'}{'b': 17', '18', '17', '4', '7', '7', '8', '11', '18, 'second coupling means A, A between the lower mandrel and the hydraulic actuating assembly -, A, -, , with the second coupling means connecting the lower mandrel and the hydraulic actuating assembly against rotation but permitting relative axial movement,'}{'b': 3', '17, 'wherein, upon rotation of the upper mandrel relative to the lower mandrel, the quick thread connection between the upper mandrel and the lower mandrel is disconnected and the upper mandrel can be moved upwardly to ...

Pressure Activated Down Hole Systems and Methods

Systems and methods for activating a down hole tool in a wellbore. A piston is moveable from a first position to a second position for activating the down hole tool. The piston includes a first side exposed to an activation chamber, and a second side operatively coupled to the down hole tool. A rupture member has a first side exposed to the activation chamber and a second side exposed to the interior of a base pipe. The rupture member is configured to rupture when a pressure differential between the activation chamber and the interior reaches a predetermined threshold value, at which point the rupture member allows fluid communication between the interior and the activation chamber to pressurize the activation chamber and move the piston, thereby activating the down hole tool.

SYSTEM FOR SETTING A DOWNHOLE TOOL

A downhole tool includes a tool member having a radially outer surface and a radially inner surface. The radially inner surface includes an angled section. A drive member is axially spaced from the tool member. The drive member includes a radially outer surface portion and a radially inner surface portion. The radially outer surface portion includes an angled portion. A seal element is provided on the drive member. The seal element includes a first portion coupled to the radially outer surface portion and a second portion that is radially outwardly disengagable from the radially outer surface portion in response to one of fluid pressure and fluid flow. 1. A downhole tool comprising:a tool member including a radially outer surface and a radially inner surface, the radially inner surface including an angled section;a drive member axially spaced from the tool member, the drive member including a radially outer surface portion and a radially inner surface portion, the radially outer surface portion including an angled portion; anda seal element provided on the drive member, the seal element including a first portion coupled to the radially outer surface portion and a second portion that is radially outwardly disengagable from the radially outer surface portion in response to one of fluid pressure and fluid flow.2. The downhole tool according to claim 1 , wherein the drive member includes a first end engageable with the tool member and a second end axially spaced from the tool member claim 1 , the angled portion extending from the first end toward the second end.3. The downhole tool according to claim 2 , wherein the first portion of the seal element is mounted at the first end and the second portion extends toward the second end along the angled portion.4. The downhole tool according to claim 1 , wherein the first portion of the seal element is formed from a first material having a first stiffness and the second portion of the seal element is formed from a second ...

PACKER ASSEMBLY INCLUDING A SUPPORT RING

A packer system includes a gauge ring, an expanding ring arranged adjacent to the gauge ring, a back-up ring, a packer element arranged adjacent to the back-up ring, and a support ring arranged between the back-up ring and the expanding ring. The support ring promotes radial outward expansion of the expanding ring. 1. A packer system comprising:a gauge ring;an expanding ring arranged adjacent to the gauge ring;a back-up ring;a packer element arranged adjacent to the back-up ring; anda support ring arranged axially between the back-up ring and the expanding ring, the support ring promoting radial outward expansion of the expanding ring.2. The packer system according to claim 1 , wherein the expanding ring includes a first angled surface defining a first angle and a second angled surface defining a second angle.3. The packer system according to claim 2 , wherein the first angle is distinct from the second angle.4. The packer system according to claim 2 , wherein the support ring includes a first angled surface portion defining a third angle and a second angled surface portion defining a fourth angle.5. The packer system according to claim 4 , wherein the first angled surface portion nests against the second angled surface.6. The packer system according to claim 5 , wherein the third angle and the second angle are complimentary angles.7. A resource exploration and recovery system comprising:a surface system; and a gauge ring;', 'an expanding ring arranged adjacent to the gauge ring;', 'a back-up ring;', 'a packer element arranged adjacent to the back-up ring; and', 'a support ring arranged axially between the back-up ring and the expanding ring, the support ring promoting radial outward expansion of the expanding ring., 'a downhole system including a string of tubulars, at least one of the string of tubulars supporting a packer system comprising8. The resource exploration and recovery system according to claim 7 , wherein the expanding ring includes a first axial end ...

Packer

A packer for a well is described. The packer comprises a seal element and seal setting apparatus. The seal setting apparatus is moveable with respect to the seal element in a setting direction to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which, in use, the seal element forms a contact seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction, will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

Interventionless Packer Setting Tool

A packer setting mechanism has a series of fingers with tabs protruding into the mandrel bore. An object such as a plug is landed on the protruding tabs and pressure is applied. The fingers extend from a ring whose movement triggers the packer to set by driving out slips on cones and compressing a sealing element. When the packer set, tensile stress builds in the fingers and a reduced dimension location on the fingers just above the tabs pulls apart. The plug drives the fingers outwardly by pushing them along a ramp against an opposing spring force. The plug clears the tabs as the tabs are driven outwardly on respective ramps such that the tabs are precluded to enter the bore as the plug clears. The drift dimension in the mandrel is preserved when the plug clears. 1. A subterranean compression set packer setting assembly for a packer comprising a sealing element and at least one slip , comprising:a mandrel having a passage therethrough, said passage having a drift dimension, said mandrel comprising ends for attachment to a tubular string;a setting sleeve on said mandrel and extending at least in part through at least one wall opening in said mandrel to present at least one movable support in said passage;said setting sleeve movable with pressure applied to an object passing through said drift dimension and landed on said support in said passage to set said seal and slip.2. The assembly of claim 1 , wherein:said support movable in said passage to retract from a central axis of said passage to beyond said drift dimension.3. The assembly of claim 1 , wherein:said object displaces said support axially.4. The assembly of claim 1 , wherein:said object displaces said support radially.5. The assembly of claim 1 , wherein:said at least one support comprises a plurality of supports each extending through a respective said opening.6. The assembly of claim 5 , wherein:said supports are circumferentially spaced.7. The assembly of claim 1 , wherein:said setting sleeve comprises a ...

Slip Assembly for Anchoring Downhole Plugs and Retainers

A downhole plug assembly can be installed at a desired location within a subterranean wellbore that is capable of isolating one portion of the wellbore from another, while sealing fluid pressure within the wellbore from at least one direction. The plug assembly can include certain components constructed of non-metallic material that can be drilled, milled or mechanically broken up more quickly and efficiently than conventional wellbore plugs, thereby facilitating removal of said plug assembly when desired. 1. A slip assembly for gripping an internal surface of a wellbore comprising:a) a cone member having a plurality of recessed slots disposed in spaced relationship around the outer circumference of said cone member, wherein said recessed slots define inclined surfaces;b) a plurality of slip members, each having a leading end and a trailing end, wherein at least one slip member is slidably disposed within each of said recessed slots; andc) a push ring operationally linked to said slip members, wherein axial movement of said push ring toward said cone member causes said slip members to interact with said inclined surfaces and extend radially outward.2. The slip assembly of claim 1 , wherein each of said slip members are wedge-shaped.3. The slip assembly of claim 2 , wherein each wedge-shaped slip member is slidably disposed on an inclined surface of a recessed slot of said cone member claim 2 ,4. The slip assembly of claim 1 , wherein each of said slip members further comprises at least one dovetail projection extending laterally from said slip member at said trailing end.5. The slip assembly of claim 4 , wherein each of said dovetail projections is slidably disposed within an aligned recess in said push ring.6. The slip assembly of claim 5 , wherein each dovetail projection travels within said aligned recess in a direction that is substantially normal to said push ring.7. The slip assembly of claim 1 , wherein each of said slip members further comprises at least one ...

Stinger for Communicating Fluid Line with Downhole Tool

A stinger is stabbed into a bore opening of a downhole tool to communicate fluid from a fluid line to the downhole tool. The stinger body defines a bore that communicates with the bore opening of the tool when the stinger body is installed in the downhole tool. An external surface of the stinger body can seal and lock inside an inside surface of the tool's bore opening when the stinger body is installed therein. The stinger body has a flow passage connected to the fluid line. A stinger port in the external surface of the stinger body is in communication with the flow passage and positions in fluid communication with a tool port inside the tool's bore opening so fluid can be communicated to the downhole tool. 1. A stinger for communicating fluid between a fluid line and a downhole tool , the downhole tool disposed with tubing , the fluid line running through the tubing , the downhole tool having a tool bore for passage of tubing flow therethrough , the tool bore defining a tool port in an internal surface of the tool bore , the stinger comprising:a body having a proximal end and a distal end and defining a body bore for passage of the tubing flow therethrough between the proximal and distal ends,the body having a flow passage therein in communication with the fluid line,the body having a stinger port in an external surface of the body, the stinger port in communication with the flow passage,the body being configured to insert at least partially into the tool bore of the downhole tool,the body bore being configured to communicate with the tool bore for the passage of the tubing flow therethrough,the stinger port in the external surface being configured to position in fluid communication with the tool port in the internal surface.2. The stinger of claim 1 , wherein the flow passage comprises a first connection disposed toward the proximal end claim 1 , the first connection configured to connect the flow passage to the fluid line.3. The stinger of claim 2 , wherein the ...

DOWNHOLE APPARATUS

Downhole apparatus comprises a base pipe and a plurality of non-concentric pressure deformable chambers mounted externally on the pipe. The chambers may be inflated to increase the diameter of the apparatus and engage and support a surrounding bore wall. 179-. (canceled)80. A downhole apparatus comprising:a base pipe; anda fluid pressure deformable chamber mounted thereon, the chamber having a plastically deformable wall, the chamber further having a pre-activation first configuration and an activated second configuration, wherein on inflation and activation of the chamber from the first configuration to the second configuration, the chamber wall undergoes plastic deformation.81. The apparatus of claim 80 , wherein the chamber extends axially along the base pipe.82. The apparatus of claim 80 , wherein the chamber extends circumferentially around the base pipe.83. The apparatus of claim 80 , wherein the chamber is non-concentrically mounted on the base pipe.84. The apparatus of claim 80 , wherein the chamber encircles the base pipe to create a ring-shaped chamber.85. The apparatus of claim 80 , comprising a valve arrangement for controlling the flow of fluid into or from the chamber.86. The apparatus of claim 85 , wherein the valve arrangement comprises a one-way valve.87. The apparatus of claim 86 , wherein the one-way valve allows fluid to flow into the chamber.88. The apparatus of claim 80 , wherein the chamber is adapted to retain an inflated configuration in the absence of inflating pressure.89. The apparatus of claim 80 , comprising a sealing element.90. The apparatus of claim 89 , wherein the sealing element is located externally of the chamber.91. The apparatus of claim 89 , wherein the sealing element is adapted to be supported by the chamber.92. The apparatus of claim 89 , wherein the sealing element comprises an elastomer.93. The apparatus of claim 89 , wherein upon inflation and activation of the chamber claim 89 , the chamber increases the diameter ...

SELF-INFLATING HIGH EXPANSION SEAL

Embodiments described herein provide a downhole tool (e.g., a retrievable bridge plug) that includes a sealing device and a load retention/equalization mechanism. The sealing device includes an elastomer seal component and an expansion device configured to radially expand outwardly to compress the elastomer seal component against a wellbore casing within which the downhole tool is located. The sealing device further includes lower and upper support barriers configured to radially expand outwardly against the wellbore. The sealing device also includes a seal energizing spring configured to maintain an initial setting force of the elastomer seal component against the wellbore casing. The load retention/equalization mechanism includes a spool/inflation valve configured to direct fluid into an internal volume to inflate the elastomer seal component radially outwardly based on a differential pressure between a first volume uphole relative to the downhole tool and a second volume downhole relative to the downhole tool. 1. A method , comprising:running a downhole tool into a wellbore formed by a wellbore casing, wherein the downhole tool comprises a sealing device and a load retention/equalization mechanism;outwardly radially expanding lower support barriers of the sealing device against the wellbore casing;outwardly radially expanding an expansion device of the sealing device to compress an elastomer seal component of the sealing device against the wellbore casing;using a seal energizing spring of the sealing device to maintain an initial setting force of the elastomer seal component against the wellbore casing;outwardly radially expanding upper support barriers of the sealing device against the wellbore casing; andusing a spool/inflation valve of the load retention/equalization mechanism to direct fluid into an internal volume within the expansion device to inflate the elastomer seal component radially outwardly to create a main setting force of the elastomer seal ...

Dissolvable pump down devices, dissolvable pump down assemblies, and methods to propel a bottomhole assembly through a lateral section of a wellbore

Dissolvable pump down devices, dissolvable pump down assemblies, and methods to propel a bottomhole assembly through a lateral section are presented. A dissolvable pump down device includes an engageable portion, and one or more expandable pieces that are initially in a first position before the dissolvable pump down device is deployed in a wellbore, and configured to expand from the first position to a second position in response to a force generated by fluid flow of fluid through the wellbore. A diameter of the expandable pieces while the expandable pieces are in the first position is less than the diameter of the one or more expandable pieces while the one or more expandable pieces are in the second position. The engageable portion and the one or more expandable pieces are configured to dissolve after the dissolvable pump down device is positioned at the desired wellbore location.

WELL PLUG ANCHOR TOOL

A plug assembly, an anchor tool for a plug, and methods for deploying a plug in a wellbore, of which the anchor tool includes a body, engaging members coupled with the body and configured to expand outward from the body, and a sliding sleeve positioned at least partially around the body. When the sliding sleeve is in a first position, the sliding sleeve covers the engaging members and restrains the engaging members from expanding, and when the sliding sleeve is in a second position, the sliding sleeve uncovers the engaging members and permits the engaging members to expand. The anchor tool also includes a friction-inducing member positioned around the body, and a shearable member coupled with the friction-inducing member and the body. The shearable member restrains the friction-inducing member, causing the friction-inducing member to maintain the sliding sleeve in the first position, until the shearable member is sheared. 1. An anchor tool for a plug , comprising:a body;engaging members coupled with the body and configured to expand outward from the body;a sliding sleeve positioned at least partially around the body, wherein, when the sliding sleeve is in a first position, the sliding sleeve at least partially covers the engaging members and restrains the engaging members from expanding, and when the sliding sleeve is in a second position, the sliding sleeve uncovers the engaging members and permits the engaging members to expand;a friction-inducing member positioned at least partially around the body; anda shearable member coupled with the friction-inducing member and the body, wherein the shearable member restrains the friction-inducing member, causing the friction-inducing member to maintain the sliding sleeve in the first position, until the shearable member is sheared.2. The tool of claim 1 , further comprising first biasing members positioned between the engaging members and the body claim 1 , wherein the engaging members are biased radially outwards by the ...

DOWNHOLE PACKER ASSEMBLY

The present invention relates to a downhole packer assembly for expansion of a metal sleeve, such as a metal patch, in a well downhole in a well tubular metal structure, comprising a body part and an expandable tubular element surrounding the body part and each end of the expandable tubular element being connected with the body part, providing an expandable space therebetween, the expandable space being fillable with liquid during expansion, the expandable tubular element having an outer face and an inner face, the expandable tubular element comprising an elastomeric or rubber material having a friction coefficient, wherein the expandable tubular element comprises a friction-enhancing material providing a higher friction coefficient of the outer face than the friction coefficient of the elastomeric or rubber material. The invention also relates to a downhole system comprising the downhole packer assembly and a positive displacement pump for expanding the expandable tubular element.

ANCHOR MODULE FOR ANCHORING TO A CASING, A CASING PLUG ASSEMBLY AND A METHOD FOR SETTING TWO CASING PLUGS IN ONE RUN

An anchor module has an inner mandrel having a through bore, a slips device, upper and lower slips supports, and a spring device radially outside of the inner mandrel. The slips device is biased to a run state. A fluid actuation system counteracts the biasing force and includes a lower piston axially displaceable within a lower fluid chamber, an upper piston axially displaceable within an upper fluid chamber, and a fluid restriction provided in the bore. A lower fluid line is provided between the bore and the lower fluid chamber. The upper and lower pistons are connected to the lower slips device. An upper fluid line is between the bore and the upper fluid chamber. A cross sectional area of the fluid bore at the entrance of the upper fluid line smaller than the cross sectional area of the fluid bore at the entrance of the lower fluid line. 1. An anchor module for anchoring to a casing , comprising:an inner mandrel having a through bore;a slips device provided radially outside the inner mandrel;upper and lower slips supports for supporting the slips device in a run state, in which the slips device is radially retracted, and for supporting the slips device in a set state, in which the slips device is radially expanded;a spring device provided radially outside of the inner mandrel, wherein the slips device is biased to the run state by means of the spring device;a fluid actuation system configured to counteract the biasing force provided by the spring device, thereby causing the slips device to move from the run state to the set state;wherein the fluid actuation system comprises a lower piston axially displaceable within a lower fluid chamber, wherein a lower fluid line is provided between the bore and the lower fluid chamber, wherein the lower piston is a part of or is connected to the lower slips device;wherein the fluid actuation system further comprises an upper piston axially displaceable within an upper fluid chamber, wherein an upper fluid line is provided ...

Method and apparatus for a wellbore assembly

A method and apparatus for a wellbore assembly. The wellbore assembly may comprise a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline; an accumulator system connected to the conveyance member; and a setting tool connected to the accumulator system. The accumulator system may be configured to supply a fluid pressure to actuate the setting tool. A method of operating a wellbore tool may comprise lowering a wellbore assembly into a wellbore using a conveyance member including at least one of a continuous spooled rod, a wireline, and a slickline, wherein the wellbore assembly includes an accumulator system and a setting tool. The method may comprise actuating the accumulator system to provide a fluid pressure to the setting tool. The method may comprise actuating the setting tool using the fluid pressure.

Wellbore apparatus for setting a downhole tool

A method of separating a downhole tubular includes running a tool into a wellbore to a predetermined location on a work string and actuating flow actuated slips. The method also includes maintaining slips in a set position by providing a first upward force on the work string. The method further includes rotating the work string to separate an upper portion of the tubular from a lower portion using a cutter assembly disposed on the work string below the slips and pulling the upper portion of the tubing and the tool from the wellbore.

Control Line Set ESP Packer With Anti-Preset Device

An apparatus and method of this disclosure include a downhole tool containing an anti-preset device in communication with a setting chamber configured to actuate at least one tool set feature of the downhole tool such as a cone-and-slip arrangement. The anti-preset device includes a control line with a port to setting chamber and a first rupture disk that prevents a control line fluid from passing through the port to the setting chamber until a first predetermined fluid pressure is achieved in the control line, the first predetermined fluid pressure being a burst pressure of the first rupture disk and achieved when the downhole tool is a desired depth with a wellbore. 1. A downhole tool comprising:a setting chamber configured to actuate at least one tool set feature of the downhole tool;a control line including a port configured for fluid communication with the setting chamber;the control line further including a first rupture disk configured to prevent a control line fluid from passing through the port to the setting chamber until a first predetermined fluid pressure is achieved in the control line, the first predetermined fluid pressure being a burst pressure of the first rupture disk.2. The downhole tool of claim 1 , wherein the downhole tool is a multi-string packer.3. The downhole tool of claim 1 , wherein the burst pressure of the first rupture disk is in a range of 500 psi to 10 claim 1 ,000 psi.4. The downhole tool of claim 1 , wherein the burst pressure of the first rupture disk is in a range of 2 claim 1 ,000 psi to 5 claim 1 ,000 psi.5. The downhole tool of claim 4 , the burst pressure of the first rupture disk being in a range of 3 claim 4 ,000 psi to 4 claim 4 ,000 psi.6. The downhole tool of claim 5 , the burst pressure of the first rupture disk being in a range of 3 claim 5 ,200 psi to 3 claim 5 ,600 psi.7. The downhole tool of claim 1 , wherein the control line fluid is hydraulic fluid.8. The downhole tool of claim 1 , further comprising the control ...

SETTING AND UNSETTING A PRODUCTION PACKER

A packer assembly includes a tubing string disposed in a wellbore and a packer releasably coupled to the tubing string. The packer includes a housing releasably coupled to the tubing string, a packer slip, a flexible sealing element, a piston coupled to the housing, a locking member, and a mandrel disposed inside the housing. The piston moves to activate the packer slip and the flexible sealing element to set the packer on a wall of the wellbore. The locking member engages the piston to constrain movement of the piston to keep the packer set on the wall of the wellbore. The mandrel connects to the tubing string when the tubing string is released from the housing. The locking member is collapsible to disengage the piston to unset the packer slip and the flexible sealing element responsive to shear force applied by the mandrel to the locking member. 1. A packer assembly comprising:a tubing string configured to be disposed in a wellbore; and a housing releasably coupled to the tubing string,', 'a packer slip coupled to the housing,', 'a flexible sealing element coupled to the housing,', 'a movable piston coupled to the housing, the movable piston configured to move to activate the packer slip and the flexible sealing element to set the packer slip and the flexible sealing element on a wall of the wellbore,', 'a locking member coupled to the housing, the locking member configured to engage the piston to constrain movement of the piston to keep the packer slip and the flexible sealing element set on the wall of the wellbore, and', 'a mandrel disposed inside the housing, the mandrel configured to connect to the tubing string when the tubing string is released from the housing, wherein the locking member is collapsible to disengage the piston to unset the packer slip and the flexible sealing element responsive to shear force applied by the mandrel to the locking member., 'a packer releasably coupled to the tubing string, the packer comprising,'}2. The packer assembly of ...

TESTABLE ISOLATION PACKER

Certain aspects are directed to a testable isolation packer that sets and provides the ability to test upper and lower packer elements. In one aspect, the testable isolation packer includes at least two packer elements, a packer element setting system, a bypass system, and a testing subassembly. The testing subassembly generally includes a moveable element with an outer port and a sealing element, an inner mandrel with an inner port, and a shear mechanism to cause travel of the moveable element close the bypass system and to open the testing subassembly. 110-. (canceled)11. A method for testing an isolation packer in a wellbore casing , comprising:(a) running at least one testable isolation packer system into the wellbore casing on a completion string;(b) starting to set an upper packer element between the wellbore casing and the completion string;(c) starting to set a lower packer element between the wellbore casing and the completion string;(d) allowing bypass of fluid from an annulus space between the upper packer element and the lower packer element to a location downhole of the lower packer element through a bypass system; and(e) causing a movable element to travel and (i) close the bypass system and (ii) open a testing subassembly.12. The method of claim 11 , further comprising anchoring a slip system into place between the wellbore casing and the completion string.13. The method of claim 11 , wherein the movable element comprises a sealing element and an outer port claim 11 , wherein the completion string comprises an inner mandrel with an inner port claim 11 , and wherein travel of the movable element moves the sealing element to a location that is not between the outer port and the inner port.14. The method of claim 11 , further comprising:(f) pressurizing the completion string such that pressure is directed to the annulus space between the deployed upper packer and lower packer elements; and(g) determining whether (1) pressure is maintained to indicate a ...

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 ...

Improvements In Or Relating To Well Abandonment

An apparatus and method for anchoring a string at a well for the purpose of cutting a tubular () which includes an anchor mechanism () being a tubular body () having a cone () arranged around the body, a plurality of selectively operable slips (), and a plurality of pistons (), there being a piston for each slip, each piston being operable to act to move each slip independently over the cone between a retracted configuration and an extended configuration wherein the outer surface () of each of the slips contacts the inner surface of the tubular (). The method includes the action of cutting the tubular () with a cutting tool () which is stabilised by the slips (). 1. Apparatus for anchoring a string at a well for the purpose of cutting a tubular , including an anchor mechanism , the anchor mechanism comprising:a tubular body having a central bore between a first inlet and a first outlet, the first inlet and first outlet being adapted for connection in a drill string to be run into the tubular;a cone arranged around the tubular body, the cone having an outer surface including a slope;a plurality of selectively operable slips, each slip having an outer surface configured to grip an inner surface of the tubular and an inner surface matching the slope of the cone they are arranged upon; anda plurality of pistons, there being a piston for each slip, each piston being operable to act to move each slip independently over the cone between a retracted configuration and an extended configuration wherein the outer surface of each of the slips contacts the inner surface of the tubular.2. Apparatus according to wherein the tubular body is rotatable relative to the cone.3. Apparatus according to wherein each piston comprises a piston rod contained within a cylinder arranged co-linearly with a central axis of the apparatus and each piston rod is arranged to act on a face of each slip.4. Apparatus according to wherein the pistons are hydraulically operated by action of fluid from ...

Well tool assembly

The invention relates to a well tool assembly ( 1 ) comprising a setting tool ( 10 ) and a plugging tool ( 20 ). The plugging tool ( 20 ) comprises: an inner mandrel device ( 21 ) and an outer housing device ( 26 ), an upper sealing device ( 30 ), a slips device ( 40 ), a lower sealing device ( 50 ) and a centralizing device ( 60 ) connected to each other in an axial direction outside of the mandrel device 21 . The slips device ( 40 ) is provided axially between the upper and lower sealing devices ( 30, 50 ). The centralizing device ( 60 ) is provided below the lower sealing device ( 50 ) or above the upper sealing device ( 30 ). When the centralizing device ( 60 ) is provided below the lower sealing device ( 50 ), the upper sealing device ( 30 ), the slips device ( 40 ), the lower sealing device ( 50 ) and the upper section ( 61 ) of the centralizing device ( 60 ) are axially displaceable downwardly and upwardly in relation to the mandrel device ( 21 ) and the upper section ( 31 ) of the upper sealing device ( 30 ) is connected to the outer housing device ( 26 ) and the lower section ( 62 ) of the centralizing device ( 60 ) is fixed to the inner mandrel device ( 21 ). When the centralizing device ( 60 ) is provided above the upper sealing device ( 30 ), the centralizing device ( 60 ), the upper sealing device ( 30 ), the slips device ( 40 ) and the upper section ( 51 ) of the lower sealing device ( 50 ) are axially displaceable downwardly and upwardly in relation to the mandrel device ( 21 ) and the upper section ( 61 ) of the centralizing device ( 60 ) is connected to the outer housing device ( 26 ) and the lower section ( 52 ) of the lower sealing device ( 50 ) is fixed to the inner mandrel device ( 21 ).

Packer Assembly Having Dual Hydrostatic Pistons for Redundant Interventionless Setting

A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. A first activation assembly initially prevents movement of the first piston. A second activation assembly initially prevents movement of the second piston. A seal assembly is disposed about the packer mandrel between the first and second pistons such that actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly and actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly to radially expand the seal assembly. 1. A packer assembly for use in a wellbore comprising:a packer mandrel;a first piston slidably disposed about the packer mandrel defining a first chamber therewith;a first activation assembly disposed about the packer mandrel initially preventing movement of the first piston;a second piston slidably disposed about the packer mandrel defining a second chamber therewith;a second activation assembly disposed about the packer mandrel initially preventing movement of the second piston; anda seal assembly disposed about the packer mandrel and positioned between the first and second pistons;wherein, actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly; andwherein, actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly ...

PRESSURE BALANCED SETTING TOOL

A system including a downhole device coupled to a pressure balanced setting tool. The setting tool may be pressure balanced to lock a setting piston in place as the system is deployed into a well. That is, in spite of downhole well pressures, no substantial differential may emerge between the setting piston and the annular space of the well adjacent the system. Thus, the setting piston may remain locked in place until triggered for setting. This may include breaching a rupture disc of another piston to disrupt hydraulic communication between the setting piston and the annular space. This allows subsequent triggering, for example through another breach of a rupture disc defining a volumetric chamber, to take place in a manner that allows stroking of the setting piston. In this way, the setting tool may be utilized to achieve setting of the downhole device. 1. A system for positioning downhole in a well at an oilfield and exposing to an annulus of the well , the system comprising:a downhole device for supporting an application in the well;a setting piston coupled to the downhole device for stroking to actuate the device, the setting piston defining a setting chamber; anda pressure balanced setting tool with an isolation mechanism defining a channel for optional hydraulic communication between the setting chamber and the annulus to hydraulically lock the setting piston.2. The system of wherein the downhole device is one of a packer claim 1 , a sliding sleeve and a valve.3. The system of wherein the device is the packer set by the stroking of the setting piston and the application is production of downhole fluids through a production tubular running through the packer and to the oilfield.4. A pressure balancing downhole setting tool for deployment into a well and exposing to an annulus thereof claim 1 , the tool comprising:a hydraulic control line coupled to a setting chamber defined by a setting piston, the setting piston for stroking to actuate a downhole device ...

RUNNING TOOL FOR AN EXPANDABLE TUBULAR

A system for subterranean deployment in a wellbore includes an expandable tubular having an outer surface supporting at least one anchor slip and an inner surface including a running tool engagement element, and a running tool for deploying the expandable tubular into the wellbore. The running tool includes an inner surface portion defining a passage and an outer surface portion supporting a forcing cone for expanding at least a portion of the expandable tubular, and a tubular support system selectively engaging with the running tool engagement element. 1. A system for subterranean deployment in a wellbore comprising:an expandable tubular including an outer surface supporting at least one anchor slip and an inner surface including a running tool engagement element; anda running tool for deploying the expandable tubular into the wellbore, the running tool including an inner surface portion defining a passage and an outer surface portion supporting a forcing cone for expanding at least a portion of the expandable tubular, and a tubular support system selectively engaging with the running tool engagement element.2. The system according to claim 1 , wherein the running tool engagement element comprises a plurality of teeth formed in the inner surface of the expandable tubular.3. The system according to claim 2 , wherein the plurality of teeth are defined by a plurality of threads.4. The system according to claim 2 , wherein the tubular support system includes a dog selectively radially inwardly shiftably supported upon the outer surface portion claim 2 , the dog including a plurality of features that are selectively engageable with the plurality of teeth.5. The system according to claim 4 , wherein the tubular support system includes a dog body that guides the dog between a deployed position and a non-deployed position.6. The system according to claim 4 , wherein the tubular support system includes a dog support that is slideably mounted to the outer surface portion of ...

WELLBORE ISOLATION DEVICE WITH TELESCOPING SETTING SYSTEM

A wellbore isolation is introduced into a wellbore and includes an elongate body defining an interior and comprising an upper sub, a lower sub, and a mandrel extending therebetween. A sealing element is disposed about the mandrel and upper and lower slip assemblies are positioned on opposing axial ends of the sealing element. A setting piston is positioned within a piston chamber defined by the lower sub and the mandrel, and a mandrel plugging device is positioned within the mandrel. The mandrel plugging device plugs the interior and transitions between occluding setting ports defined in the mandrel and exposed the setting ports to facilitate fluid communication between the interior and the piston chamber. The interior is pressurized to actuate the setting piston and set the lower slip assembly, and further pressurized to move the mandrel and set the upper slip assembly. 1. A method , comprising: an elongate body that defines an interior and comprises an upper sub, a lower sub, and a mandrel extending between the upper and lower subs;', 'a sealing element disposed about the mandrel;', 'an upper slip assembly positioned on a first axial end of the sealing element and a lower slip assembly positioned on a second axial end of the sealing element;', 'a setting piston positioned within a piston chamber cooperatively defined by the lower sub and the mandrel; and', 'a mandrel plugging device positioned within the mandrel;, 'introducing a wellbore isolation device into a wellbore lined with casing, the wellbore isolation device includingplugging the interior with the mandrel plugging device;transitioning the mandrel plugging device from a first state, where the mandrel plugging device occludes setting ports defined in the mandrel, to a second state, where the setting ports are exposed to facilitate fluid communication between the interior and the piston chamber;pressurizing the interior to a first pressure and thereby actuating the setting piston to set the lower slip ...

SLIP ASSEMBLY

The presently disclosed subject matter relates to methods and apparatus associated with a slip assembly. The slip assembly comprises a plurality of slip segments, wherein each of the plurality of slip segments and a bonding substrate. The slip segments comprise: a first end having a plurality of teeth; a second end opposite the first end; and a transition section between the first end and the second end. The bonding substrate is disposed within the transition sections. The disclosed methods pertain to the manufacture and deployment of such an apparatus. 13-. (canceled)4. A slip assembly , comprising: a first axial portion having a first set of teeth on an outer surface thereof; and', 'a second axial portion having a second set of teeth on an outer surface thereof; and, 'a first slip segment comprisinga first cured bonding material positioned between the first and second axial portions.5. The slip assembly of claim 4 , further comprising a second slip segment that is circumferentially adjacent to the first slip segment claim 4 , wherein the first cured bonding material holds the first and second slip segments in place claim 4 , relative to one another claim 4 , until the first cured bonding material breaks.6. The slip assembly of claim 4 , further comprising a second slip segment that is circumferentially-offset from the first slip segment claim 4 , wherein the second slip segment comprises:a first axial portion having a first set of teeth on an outer surface thereof; anda second axial portion having a second set of teeth on an outer surface thereof, wherein the first cured bonding material is also positioned circumferentially-between the respective first axial portions of the first and second slip segments.7. The slip assembly of claim 4 , wherein the first cured bonding material is positioned within a recess between the first and second sets of teeth.8. The slip assembly of claim 4 , further comprising a second cured bonding material positioned on an inner surface ...

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.

DOWNHOLE DEVICE AND DOWNHOLE SYSTEM

The present invention relates to a downhole device for being moved downwards in a well by fluid to assist stimulation of a production zone of the well, the well comprising a well tubular structure having a first opening and a first movable sleeve arranged opposite the first opening, and the well tubular structure having an inner diameter, the downhole device having an axial extension, and comprising: a first part comprising two projection elements having a profile matching grooves in the sleeve, and a second part comprising: a body, two anchor elements projectable from the body for anchoring the second part in the well tubular structure, and a sealing element configured to seal against the well tubular structure, the downhole device further comprising: a displacement mechanism comprising a piston movable within a piston cylinder to displace, in the axial extension, the first part in relation to the second part when anchored in the well tubular structure to operate the sleeve. The invention also relates to a downhole system for stimulating a formation surrounding a well tubular structure of a well. Finally, the present invention relates to a stimulation method for stimulating a formation by means of a downhole system according to the invention. 115.-. (canceled)17. A downhole device according to claim 16 , wherein the displacement mechanism further comprises a spring being compressed during movement of the piston in relation to the piston cylinder.18. A downhole device according to claim 16 , wherein the sealing element is a cup seal.19. A downhole device according to claim 16 , wherein each projection element is movable in a radial direction in and out of a projection cylinder.20. A downhole device according to claim 19 , wherein the projection cylinder is fluidly connected with the piston cylinder so that fluid in the piston cylinder forces the projection element out of the projection cylinder upon movement of the piston into the piston cylinder.21. A downhole ...

Subterranean Packer Sealing System Load Diverter

A mandrel and a packer outer assembly are formed to create spring compartments on opposed sides of a sealing element. The outer assembly is shear pinned to the mandrel to minimize spring travel during setting. Once set in the normal way the presence of the springs transfers load and sustained loads through the connected tubular string in either direction. A load coming from downhole and acting in an uphole direction first compresses the spring located uphole from the sealing assembly so that the loading goes behind the sealing assembly and into the upper spring and ultimately to the upper slips. The reverse happens when the force is coming from uphole of the sealing assembly and acting in a downhole direction. The springs can be a coil, a stack of Belleville washers, fluid pushed through an orifice, a resilient material or a contained compressible fluid, to name some examples. 1. A packer for subterranean use against a borehole wall , comprising:a mandrel supporting an outer assembly further comprising a sealing element flanked on opposing sides with an uphole and a downhole slip assembly;said mandrel, after said sealing element and slip assemblies are engaged to the borehole wall, transmitting at least a portion of applied forces thereto in either an uphole or downhole direction, in an alternate path that avoids incremental loading of said sealing assembly.2. The packer of claim 1 , wherein:said alternate path runs through said mandrel.3. The packer of claim 1 , wherein:a force in an uphole direction on said mandrel passes at least in part under said sealing element to said uphole slip assembly.4. The packer of claim 1 , wherein:a force in a downhole direction on said mandrel passes at least in part under said sealing element to said downhole slip assembly.5. The packer of claim 1 , wherein:said mandrel defines an uphole and a downhole space on opposed sides of said sealing element whose volume varies with relative movement between said mandrel and said outer ...

DOWNHOLE CASING PULLING TOOL

A method and apparatus for cutting and pulling a casing string from a well. a downhole casing pulling tool includes a tubular housing having a bore therethrough, a packer assembly configured to isolate an annulus between a casing and the tool, a slip assembly configured to engage the casing, and a piston assembly disposed in the bore of the tubular housing. The piston assembly is configured to operate an actuator, wherein the actuator is configured to operate at least one of the packer assembly and the slip assembly and modify a fluid pressure in the bore of the tubular housing. 1. A downhole casing pulling tool , comprising:a tubular housing having a bore therethrough;a packer assembly configured to isolate an annulus between a casing and the tool;a slip assembly configured to engage the casing; and operate an actuator, wherein the actuator is configured to operate at least one of the packer assembly and the slip assembly; and', 'modify a fluid pressure in the bore of the tubular housing., 'a piston assembly disposed in the bore of the tubular housing and configured to2. The tool of claim 1 , wherein the piston assembly is longitudinally movable within the tubular housing.4. The tool of claim 3 , wherein the actuator housing is longitudinally movable relative to the guide mandrel.5. The tool of claim 1 , wherein the actuator further comprises:a slip piston coupled to the drive mandrel and configured to actuate the slip assembly; anda packer piston coupled to the actuator housing and configured to actuate the packer assembly.6. The tool of claim 1 , wherein the slip assembly comprises:a slip mandrel having a bore therethrough;at least one slip movable between an extended position and a retracted position along the slip mandrel; anda biasing member configured to bias the at least one slip towards the retracted position.7. The tool of claim 1 , wherein the packer assembly comprises:a packer mandrel having a bore therethrough;at least one packing element disposed on ...

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 ...

Polymers for Wellbore Plugs and Wellbore Stability

Apparatus, compositions, and methods for creating polymer plugs in wellbores and/or for enhancing wellbore stability, comprising: a flow control device such as a blowout preventer on a wellbore; a control fluid aperture fluidly connected with the wellbore for introducing a control fluid and/or a plug-forming agent such as a polymer, monomer, resinous, and/or crosslinkable material, through a control fluid aperture and into the primary throughbore while wellbore blowout fluid flows through the wellbore; and optionally, a weighted fluid aperture positioned in the wellbore conduit below the control fluid aperture for introducing a weighted fluid or another fluid or plug-forming agent into the wellbore. Exemplary plug-forming agents include dicyclopentadiene and norborene, and exemplary catalysts include Grubbs catalysts. The polymer plugs also may be utilized to hydraulic sealing within wellbores, such as during P&A and drilling operations for providing wellbore stability. 1. A method for creating polymer plugs within wellbores , the method comprising:combining a polymerizable plug-forming agent and a Grubbs catalyst;locating the combined plug-forming agent and the Grubbs catalyst at a selected location within the wellbore for a polymerization reaction between the plug-forming agent and the Grubbs catalyst, to create a cross-linked polymer composition within the wellbore; andallowing the plug-forming agent and the Grubbs catalyst to polymerize into the polymer plug at the selected location within the wellbore.2. The method of claim 1 , further comprising:providing the polymerizable plug-forming agent;providing the Grubbs catalyst; andcombining the plug-forming agent and the Grubbs catalyst within the wellbore.3. The method of claim 1 , further comprising:providing the polymerizable plug-forming agent;providing the Grubbs catalyst;combining the plug-forming agent and the Grubbs catalyst outside of the wellbore; andlocating the combined plug-forming agent and Grubbs ...

PACKER ASSEMBLY WITH WING PROJECTION SLIPS

A packer with a slip assembly utilizing retainable wing projections. The slip assembly is configured for anchoring the packer in a well upon setting. This setting or deployment of the slip assembly involves shearing of wing projections from the sides of the slips. In this way, the retaining of the wings by counterbore projections of the packer ceases to keep individual slips also retained. That is, the shearing now allows the slips to expand radially into the noted anchoring position. Additionally, utilizing this type of wing shearing for setting allows the wings and indeed, the majority of the slips to be of a composite polymer or other readily millable or otherwise removable material. Thus, following the isolation, a more efficient packer removal may be realized. 1. A slip assembly for interfacing a wall of a well to anchor a fluid isolating packer therein , the slip assembly comprising:a downhole cone with a plurality of spaced apart counterbore projections;a plurality of slips disposed in spaces between the counterbore projections; anda plurality of retainable wings coupled to the slips at sides thereof, each wing disposed below one of the counterbore projections in advance of the anchoring and of a predetermined shear rating for the anchoring.2. The assembly of wherein adjacent wings of adjacent slips of the pluralities are coupled to one another in advance of the anchoring.3. The assembly of wherein each slip comprises:a slip base;at least one wing of the plurality thereof coupled to the slip base;a wicker over the base and wing for the interfacing of the well wall during the anchoring.4. The assembly of wherein the wicker further comprises teeth to promote the anchoring.5. The assembly of wherein the wicker is of a material having a specific gravity substantially greater than that of the slip base and the wing.6. The assembly of wherein the wicker comprises a minority of the volume of the slip.7. The assembly of wherein the wicker is of a material selected ...

FRAC PLUG SYSTEM WITH INTEGRATED SETTING TOOL

A frac plug system downhole tool and method of securing a frac plug system in a wellbore. A mandrel extending from a first end to a second end. A setting assembly is on the first end of the mandrel and is movable along the mandrel. An anchor is at the second end of the mandrel and is expandable to engage the wellbore. A gas generates a pressure to move the setting assembly along the mandrel to expand the anchor at the second end of the mandrel.

SYSTEMS AND METHODS FOR SEALING A WELLBORE

Systems and methods for sealing a wellbore are described. The system includes a packing element configured to at least partially seal an uphole portion of a wellbore from a downhole portion of the wellbore. A first annular pressure sensor is positioned uphole of the packing element. The first annular pressure sensor is configured to measure a first pressure within the wellbore uphole of the packing element. A second annular pressure sensor is positioned downhole of the packing element. The second annular pressure sensor is configured to measure a second pressure within the wellbore downhole of the packing element. A control sub-assembly is configured to be positioned within the wellbore. The control sub-assembly is configured to monitor a sealing efficiency of the system by comparing the first pressure and the second pressure. 1. A wellbore monitoring system comprising:a packing element configured to at least partially seal an uphole portion of a wellbore from a downhole portion of the wellbore;a first annular pressure sensor positioned uphole of the packing element, the first annular pressure sensor configured to measure a first pressure within the wellbore uphole of the packing element;a second annular pressure sensor positioned downhole of the packing element, the second annular pressure sensor configured to measure a second pressure within the wellbore downhole of the packing element; anda control sub-assembly configured to be positioned within the wellbore, the control sub-assembly configured to monitor a sealing efficiency of the system by comparing the first pressure and the second pressure.2. The system of further comprising:a cylindrical body that supports the packing element, the first annular pressure sensor, the second annular pressure sensor, and the control sub-assembly;a first packer slip positioned nearer an uphole end of the cylindrical body than a downhole end of the cylindrical body, the first packer slip configured to at least partially support ...

WELLBORE STAGE TOOL WITH REDUNDANT CLOSING SLEEVES

A stage tool comprises a body with a tubular wall, defining an outer surface and an inner surface. Fluid ports, such as cement circulation ports, extend through the tubular wall. The stage tool further comprises a primary closing sleeve. The primary closing sleeve may be movable along the outer surface of the tubular wall for closing the ports when the treatment of the wellbore stage ends. A secondary closing sleeve may be movable along the inner surface of the tubular wall for closing the port in case of failure of the primary closing sleeve or for redundancy. The primary closing sleeve may be actuated by an internal member joined to the primary closing sleeve by a crosslink and movable on the inner surface. The internal member and the secondary closing sleeve may move along different surfaces on the internal wall to avoid interference. 1. A stage tool for stage treatment of a lined wellbore , comprising:a body with a longitudinal inner bore enclosed by a tubular wall with an outer surface, an inner surface and a fluid port;a primary closing sleeve, moveable on the outer surface from a port open position to a port closed position; anda secondary closing sleeve, movable on the inner surface of the body from a port uncovered position, to a port covering position.2. The stage tool as in claim 1 , further comprising an internal member joined to the primary closing sleeve and movable on the inner surface.3. The stage tool of claim 2 , wherein the internal member and the primary closing sleeve are joined by a crosslink.4. The stage tool of claim 3 , wherein the tubular wall is provided with a longitudinal channel claim 3 , shaped to enable travel of the crosslink when the primary closing sleeve moves from the port open position to port closed position.5. The stage tool of claim 2 , wherein the internal member and the secondary closing sleeve move along different surfaces on the internal wall claim 2 , to avoid interference.6. The stage tool of claim 2 , wherein the ...

Anti-preset for packers

Disclosed herein are embodiments of a packer assembly and a well system. In one embodiment, a packer assembly includes an inner mandrel; a packing element at least partially surrounding the inner mandrel; a packing element activation sleeve coupled to the packing element; a hydrostatic setting assembly engageable with the packing element activation sleeve; and a hydraulic setting assembly positioned between the packing element and the hydrostatic setting assembly. The hydrostatic setting assembly includes a hydrostatic piston; a hydrostatic prop piston engageable to push the hydrostatic piston to engage the packing element activation sleeve; and a hydrostatic locking mechanism to maintain the hydrostatic piston in a locked position. The hydraulic setting assembly includes a hydraulic piston; a hydraulic locking mechanism coupled to the hydraulic piston; and a hydraulic prop piston engageable with the hydraulic locking mechanism and operable to move the hydraulic locking mechanism between locked and unlocked position.

Borehole Data Transmission Method for Flowed Back Borehole Plugs with a Lower Slip Assembly or Object Landed on Said Plugs

A borehole plug or packer for treating is designed to be flowed back to a surface location after use. When the treatment is concluded pressure from above is relieved or lowered, and well fluid is flowed back, so that the plug or plugs disengages at slips designed to resist differential pressure from above. The application of differential pressure from below causes the lower slips to release one or more of such plugs in the hole into specialized sub surface or surface capture equipment so that well pressure is relieved before removal of the plugs from specialized subsurface or surface capture equipment. Sensors to obtain and store data can be incorporated into the plugs or into objects landed on the plugs so that when brought to the surface the data can be processed and used in aid of production. 1. A method collecting borehole data stored in at least one packer or plug assembly to a surface location , comprising:collecting borehole data during a borehole treatment against said at least one packer or plug assembly, when set, with at least one sensor located thereon;creating a differential pressure on said at least one packer or plug assembly in an uphole direction toward the surface;bringing said at least one sensor toward a surface location with at least a portion of said at least one packer or plug assembly.2. The method of claim 1 , comprising:bringing the entire at least one packer or plug assembly toward the surface.3. The method of claim 2 , comprising:providing a body on said at least one packer or plug assembly;locating said at least one sensor in said body.4. The method of claim 1 , comprising:bringing at least a portion of at least one packer or plug assembly with said sensor toward the surface.5. The method of claim 4 , comprising:locating said at least one sensor on an object removably mounted to a body of said at least one packer or plug assembly.6. The method of claim 5 , comprising:providing a seat on said body around a passage therethrough to accept ...

Plug assemblies for a subterranean wellbore

Plug assemblies for plugging a wellbore tubular and methods relating thereto are disclosed. In an embodiment, the plug assembly includes a central axis and a seal sub including a plurality of axially extending fingers and a tapered outer surface. In addition, the plug assembly includes a sealing element coupled to the axially extending fingers of the seal sub. Further, the plug assembly includes a slip sub including a tapered inner surface, and a plurality of axially extending fingers. The fingers of the slip sub each include one or more teeth. The seal sub is configured to be at least partially inserted within the slip sub so that the tapered outer surface engages with the tapered inner surface, and axial advance of the tapered inner surface within the tapered outer surface is to radially expand the fingers of the slip sub to engage with an inner surface of the tubular.

shutter for packing gravel in an alternative flow channel and method for completing a well

OBTURADOR PARA EMPACOTAMENTO DE CASCALHO EM CANAL DE FLUXO ALTERNATIVO E MÉTODO PARA COMPLETAMENTO DE UM POÇO. Aparelho e método para completamento de um poço, incluindo prover um obturador tendo um mandril interno, canais de fluxo alternativos ao longo do mandril interno, e um elemento de selagem externo ao mandril interno, incluindo conectar o obturador ao corpo tubular, em seguida introduzir o obturador e o corpo tubular conectados dentro do poço. Em um aspecto, o obturador e corpo tubular conectados podem ser colocados ao longo de uma parte de furo-aberto do poço. O corpo tubular pode ser uma peneira de areia, com a peneira de areia compreendendo um tubo de base, um meio de filtragem circundante, e canais de fluxo alternativos. O método inclui colocar um obturador e injetar uma lama de cascalho em uma região anular formada entre o corpo tubular e o poço circundante, e em seguida ainda injetar a lama de cascalho através dos canais de fluxo alternativos, para permitir que a lama de cascalho pelo menos parcialmente desvie o elemento de selagem do obturador. SHUTTER FOR PACKAGING GRAVEL IN ALTERNATIVE FLOW CHANNEL AND METHOD FOR COMPLETING A WELL. Apparatus and method for completing a well, including providing a plug having an inner mandrel, alternative flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting the plug to the tubular body, then inserting the plug. plug and tubular body connected inside the well. In one aspect, the plug and connected tubular body can be placed along a hole-open part of the well. The tubular body may be a sand sieve, with the sand sieve comprising a base tube, a surrounding filter medium, and alternative flow channels. The method includes placing a plug and injecting a gravel sludge into an annular region formed between the tubular body and the surrounding well, and then injecting the gravel sludge through the alternative flow channels, to allow the gravel sludge through least ...

一种内嵌式密封装置及其安装工具

本发明提供了一种内嵌式密封装置，包括中心管，卡瓦，锥形体，隔环和锁紧套；所述中心管的左端连接堵头或固井附件功能单元，其右端通过外螺纹与锁紧套连接；所述卡瓦为开口的锥形结构，所述锥形体为锥形管状结构，两个所述锥形体通过各自的内孔相向套在中心管的中部，两个锥形体之间设有套在中心管上的隔环；每个锥形的外锥面配合设有卡瓦；所述锁紧套开有卡簧槽，用来安装卡簧。相对于现有技术，本发明所述的内嵌式密封装置具有以下优势：所述2组加工了应力槽的卡瓦将固井附件更容易坐封在套管内壁上且可承受双向载荷，带有卡簧的锁紧套使工具更为安全。

Well formation treatment device

FIELD: oil and gas industry. SUBSTANCE: invention relates in particular to devices for separating the downhole space for pumping various reagents into the formation. The device for treating a formation in well contains an inflatable packer, which is lowered on tubing, consisting of a cup installed between the stops. The cup cavity is communicated with the tubing through a check valve installed on top of the packer and configured to prevent the inflatable packer from moving to the operating position when it moves from the well surface to the installation interval. Drain valve is located below the packer and is configured to provide fluid flow through it after the packer has moved to the operating position under the action of excess pressure. Cup and packer stops are installed outside the tubular body, connected from above with a check valve and communicated with the cup cavity by at least one radial channel. Cup is rigidly connected to the stops, one of which is movable with the possibility of hermetic longitudinal movement along the body to the other stop when the pressure in the cavity rises. Drain valve is made in form of a plug of the packer body, overlapping the inner longitudinal space of the body with possibility of detaching at pressure exceeding pressure of transition to the operating position. Check valve is connected to the tubing with an adapter inserted into the check valve, and is fixed in it by shear elements that break when the packer is lifted to prevent damage to integrity of the lift tubing. EFFECT: increase in reliability of packer installation and elimination of emergencies when lifting the packer, due to the provision of possibility of automatic disconnection of the pipe string. 4 cl, 3 dwg РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2 741 885 C1 (51) МПК E21B 33/1295 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ (52) СПК E21B 33/1295 (2020.08) (21)(22) Заявка: 2020130518, 16.09.2020 (24) Дата ...

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Apparatus and method for placing and for backwashing well filtration devices in uncased well bores

An earth well completion apparatus and method wherein a work string equipped for jet washing downhole filtration devices, such as well screens and for back washing said downhole filtration devices and containing multiple ball catcher subs which utilize the same drop ball to prevent the inadvertent operation of hydraulically powered tools as well as to permanently valve closed a portion of said work string is concentrically disposed in a production string and run in said well simultaneously. Said ball catcher sub which prevents the inadvertent actuation of said hydraulically operated tools is contained within the main fluid bore of said work string and has an expellable inner collar with an outwardly biased catcher ring which, when expelled, shears hollow shearable means thereby actuating said tool. Expansion of said catcher ring frees said drop ball to fall into a catcher sub which has a retention groove milled into its inner circumference into which said drop ball extrudes thereby preventing its expulsion due to back pressure.

Expandable packer with anchoring feature

An expandable packer or anchor is disclosed. It features a gripping device integral to or mounted in a sleeve over the mandrel and mating undulating surfaces to help maintain grip under changing load conditions. Upon expansion, pressure on a sealing element is enhanced by nodes to increase internal pressure as it engages an outer tubular. Adjacent retaining rings limit extrusion and enhance grip. A gripping device, such as wickers on slips, preferably digs into the outer tubular. The expansion is preferably by pressure and can incorporate pressure intensifiers delivered by slick line or wire line. Release is accomplished by a release tool, which is delivered on slick line or wire line. It stretches the anchor or packer longitudinally, getting it to retract radially, for release. The release tool can be combined with packers or anchors that have a thin walled feature in the mandrel, to release by pulling the mandrel apart.

One trip backwash/sand control system with extendable washpipe isolation

A travel joint and latching assembly is connected below a gravel pack service tool to set an isolation assembly while performing backwashing and gravel pack operations, in a single trip. The travel joint is protected against inadvertent expansion by a positive mechanical lock assembly which isolates and decouples mechanical loading forces which may arise during the setting of the packer and during gravel pack operations. Inadvertent set of the hydraulic packer during backwashing operations is prevented by a hydraulic setting tool which includes a shear sleeve and an expandable C-ring drop ball seat.

Hydraulic setting sleeve

A hydraulic setting apparatus has an isolation sleeve which covers setting ports and prevents entry of hydraulic setting fluid into a pressure settable tool such as an inflatable packer or a hydraulic packer. The mandrel of the setting tool is mechanically coupled to the mandrel of the pressure settable completion tool by a guide tube which provides an enlarged counterbore chamber. The guide tube is intersected by radial setting ports which permit entry of the pressurized fluid for pressurizing a hydraulic pressure chamber in the completion tool. A shiftable isolation sleeve opens and closes the setting ports. A radially outwardly biased split C-ring is engaged against the bore of the isolation sleeve. Longitudinal travel of the split C-ring is limited by a shear collar which is releasably pinned to the isolation sleeve.

Expandable packer with anchoring feature

An expandable packer or anchor is disclosed. It features a gripping device integral to or mounted in a sleeve over the mandrel and mating undulating surfaces to help maintain grip under changing load conditions. Upon expansion, pressure on a sealing element is enhanced by nodes to increase internal pressure as it engages an outer tubular. Adjacent retaining rings limit extrusion and enhance grip. A gripping device, such as wickers on slips, preferably digs into the outer tubular. The expansion is preferably by pressure and can incorporate pressure intensifiers delivered by slick line or wire line. Release is accomplished by a release tool, which is delivered on slick line or wire line. It stretches the anchor or packer longitudinally, getting it to retract radially, for release. The release tool can be combined with packers or anchors that have a thin walled feature in the mandrel, to release by pulling the mandrel apart.

Apparatus and method for placing and for backwashing well filtration devices in uncased well bores

An earth well completion apparatus and method wherein a work string equipped for jet washing downhole filtration devices, such as well screens and for back washing said downhole filtration devices and containing multiple ball catcher subs which utilize the same drop ball to prevent the inadvertent operation of hydraulically powered tools as well as to permanently valve closed a portion of said work string is concentrically disposed in a production string and run in said well simultaneously. Said ball catcher sub which prevents the inadvertent actuation of said hydraulically operated tools is contained within the main fluid bore of said work string and has an expellable inner collar with an outwardly biased catcher ring which, when expelled, shears hollow shearable means thereby actuating said tool. Expansion of said catcher ring frees said drop ball to fall into a catcher sub which has a retention groove milled into its inner circumference into which said drop ball extrudes thereby preventing its expulsion due to back pressure.

Packer

A packer for a well is described. The packer comprises at least one packing element, at least one anchoring element, and a mandrel coupled to the at least one anchoring element. The packer is arranged such that, once set, the mandrel is free to move with respect to the packing and anchoring elements. In one embodiment the at least one anchoring element is integral with the at least one packing element. In an alternative embodiment the at least one anchoring element is separate from the at least one packing element.

Packer

A packer for a well is described. The packer comprises a seal element and seal setting apparatus. The seal setting apparatus is moveable with respect to the seal element in a setting direction to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which, in use, the seal element forms a contact seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction, will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

Release mechanism for down-hole tools

Improved packer

A packer for a well is described. The packer comprises a seal element (12) and seal setting apparatus (14). The seal setting apparatus is moveable with respect to the seal element in a setting direction (X) to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which, in use, the seal element forms a contact seal with a conduit wall. In use, the packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction (X), will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

Well tool and method for pressure testing of different zones in a well

The invention relates to a well tool assembly (1) comprising a setting tool (10) and a plugging tool (20). The plugging tool (20) comprises: - an inner mandrel device (21) and an outer housing device (26), an upper sealing device (30), a slips device (40), a lower sealing device (50) and a centralizing device (60) connected to each other in an axial direction outside of the mandrel device 21. The slips device (40) is provided axially between the upper and lower sealing devices (30, 50). The centralizing device (60) is provided below the lower sealing device (50) or above the upper sealing device (30). When the centralizing device (60) is provided below the lower sealing device (50), the upper sealing device (30), the slips device (40), the lower sealing device (50) and the upper section (61) of the centralizing device (60) are axially displaceable downwardly and upwardly in relation to the mandrel device (21) and the upper section (31) of the upper sealing device (30) is connected to the outer housing device (26) and the lower section (62) of the centralizing device (60) is fixed to the inner mandrel device (21). When the centralizing device (60) is provided above the upper sealing device (30), the centralizing device (60), the upper sealing device (30), the slips device (40) and the upper section (51) of the lower sealing device (50) are axially displaceable downwardly and upwardly in relation to the mandrel device (21) and the upper section (61) of the centralizing device (60) is connected to the outer housing device (26) and the lower section (52) of the lower sealing device (50) is fixed to the inner mandrel device (21).343440

Packer

A packer for use inside a casing of a subterranean well includes a resilient element, a housing and a rupture disc. The resilient element is adapted to seal off an annulus of the well when compressed, and the housing is adapted to compress the resilient element in response to a pressure exerted by fluid of the annulus of a piston head of the housing. The housing includes a port for establishing fluid communication with the annulus. The rupture disc is adapted to prevent the fluid in the annulus from entering the port and contacting the piston head until the pressure exerted by the fluid exceeds a predefined threshold and ruptures the rupture disc.

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Systems and methods for sealing a wellbore

Systems and methods for sealing a wellbore are described. The system includes a packing element configured to at least partially seal an uphole portion of a wellbore from a downhole portion of the wellbore. A first annular pressure sensor is positioned uphole of the packing element. The first annular pressure sensor is configured to measure a first pressure within the wellbore uphole of the packing element. A second annular pressure sensor is positioned downhole of the packing element. The second annular pressure sensor is configured to measure a second pressure within the wellbore downhole of the packing element. A control sub-assembly is configured to be positioned within the wellbore. The control sub-assembly is configured to monitor a sealing efficiency of the system by comparing the first pressure and the second pressure.

Apparatus for setting hydraulic packers and for placing a gravel pack in a downhole oil and gas well

A hydraulic oil and gas well downhole packer apparatus for use in a well casing below a wellhead and in combination with a coil tubing unit provides a tool body having a longitudinally extending tool bore and an upper end portion that connects to the lower free end of the coiled tubing unit during use. The tool body includes an inner elongated hollow mandrel with a hydraulic piston movable disposed upon the external surface of the mandrel. The piston is movable between an initial "running" position and a final "setting" position. An external sleeve is engaged by the piston when it moves between the running and setting positions, the external sleeve engaging slips that expand to anchor the tool body to the well casing. An annular packer member is expandable responsive to sliding movement of the external sleeve and is positioned below the slips for forming a seal between the tool body and the casing at a position near the lower end portion of the tool body.

alternative flow channel gravel packing shutter and method for completing a well

obturador para empacotamento de cascalho em canal de fluxo alternativo e método para completamento de um poço. aparelho e método para completamento de um poço, incluindo prover um obturador tendo um mandril interno, canais de fluxo alternativos ao longo do mandril interno, e um elemento de selagem externo ao mandril interno, incluindo conectar o obturador ao corpo tubular, em seguida introduzir o obturador e o corpo tubular conectados dentro do poço. em um aspecto, o obturador e corpo tubular conectados podem ser colocados ao longo de uma parte de furo-aberto do poço. o corpo tubular pode ser uma peneira de areia, com a peneira de areia compreendendo um tubo de base, um meio de filtragem circundante, e canais de fluxo alternativos. o método inclui colocar um obturador e injetar uma lama de cascalho em uma região anular formada entre o corpo tubular e o poço circundante, e em seguida ainda injetar a lama de cascalho através dos canais de fluxo alternativos, para permitir que a lama de cascalho pelo menos parcialmente desvie o elemento de selagem do obturador. alternative flow channel gravel packing shutter and method for completing a well. apparatus and method for completing a well, including providing a plug having an inner mandrel, alternative flow channels along the inner mandrel, and an outer sealing member to the inner mandrel, including connecting the plug to the tubular body, then introducing the plug and tubular body connected inside the well. In one aspect, the connected plug and tubular body may be placed along an open-hole portion of the well. the tubular body may be a sand screen, with the sand screen comprising a base tube, a surrounding filtering means, and alternative flow channels. The method includes placing a plug and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding well, and then further injecting the gravel slurry through the alternative flow channels to allow the gravel slurry through least ...

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Method for setting a packer within a wellbore

用于替代流动通道砾石充填的封隔器和用于完成井筒的方法

用于完成井筒的设备和方法，其包括提供具有内心轴、沿内心轴的替代流动通道以及内心轴外部的密封元件的封隔器，包括将封隔器连接至管状体，随后将封隔器和连接的管状体下入井筒。在一方面，封隔器和连接的管状体可沿井筒的裸眼井部分被放置。管状体可以为砂滤器，砂滤器包括中心管、周围过滤介质和替代流动通道。该方法包括坐封封隔器并将砾石砂浆注入在管状体和周围井筒之间形成的环形区域，并且随后进一步通过替代流动通道注入砾石砂浆，以允许砾石砂浆至少部分地绕过封隔器的密封元件。

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Downhole packer and method for completing a wellbore in a subsurface formation

The present invention relates to the field of well completions and, more specifically, to the isolation of formations in connection with wellbores that have been completed using gravel-packing. An apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Empaque para filtración con grava de canal de flujo alternativo y método para completar un sondeo.

Aparato y método para completar un sondeo incluye proporcionar un filtro que tiene un mandril interior, canales de flujo alternativos a lo largo del mandril interior, y un elemento de sellado externo al mandril interior, que incluye conectar el filtro al cuerpo tubular, después meter el filtro y el cuerpo tubular conectado en el sondeo. En un aspecto, el filtro y el cuerpo tubular conectado pueden colocarse a lo largo de una porción de pozo no revestido del sondeo. El cuerpo tubular puede ser un tamiz de arena, con el tamiz de arena comprendiendo una tubería base, un medio de filtro circundante, y canales de flujo alternativos. El método incluye fraguar un filtro e inyectar una lechada de grava en una región anular formada entre el cuerpo tubular y el sondeo circundante, y después inyectar adicionalmente la lechada de grava a través de los canales de flujo alternativos para permitir que la lechada de grava desvíe por lo menos parcialmente el elemento de sellado del filtro.

Packer for alternate flow channel gravel packing and method for completing a wellbore

APPARATUS AND METHOD FOR COMPLETING A WELLBORE INCLUDING PROVIDING A PACKER HAVING AN INNER MANDREL, ALTERNATE FLOW CHANNELS ALONG THE INNER MANDREL, AND A SEALING ELEMENT EXTERNAL TO THE INNER MANDREL, INCLUDING CONNECTING PACKER TO TUBULAR BODY, THEN RUNNING THE PACKER AND CONNECTED TUBULAR BODY INTO THE WELLBORE. IN ONE ASPECT, THE PACKER AND CONNECTED TUBULAR BODY MAY BE PLACED ALONG AN OPEN-HOLE PORTION OF THE WELLBORE. TUBULAR BODY MAY BE A SAND SCREEN, WITH THE SAND SCREEN COMPRISING A BASE PIPE, A SURROUNDING FILTER MEDIUM, AND ALTERNATE FLOW CHANNELS. THE METHOD INCLUDES SETTING A PACKER AND INJECTING A GRAVEL SLURRY INTO AN ANNULAR REGION FORMED BETWEEN THE TUBULAR BODIES AND THE SURROUNDING WELLBORE, AND THEN FURTHER INJECTING THE GRAVEL SLURRY THROUGH THE ALTERNATE FLOW CHANNELS TO ALLOW THE GRAVEL SLURRY TO AT LEAST PARTIALLY BYPASS SEALING ELEMENT OF THE PACKER.

一种靠气体驱动的封隔器及封隔器坐封方法

本发明涉及一种靠气体驱动的封隔器及封隔器坐封方法，通过钻杆带压送入气体驱动坐封封隔器，实现气体钻井条件下的一趟钻中途测试，将原来的液相介质替气相、压井、中途测试、气相介质替液相，干燥井筒回复气体钻井简化为直接在气体介质条件下带压下入封隔器直接测试，测试后直接恢复气体钻井。提高了钻‑测‑完井效率，避免了水敏性地层垮塌、泥包卡钻，减少了储层污染，节约作业时间和成本，可直接将探井转为生产井，加快油气井勘探开发步伐。

Floating piston for selective hydraulic packer

A well packer of the type which is set by hydraulic pressure injected through the tubing string, having a setting chamber between the pistons therein which actuate the packer, wherein one of the pistons is floating while the packer is being lowered to compensate for thermal expansion or contraction and pressure differentials encountered as the packer is lowered in the well in order to prevent undue pressure from being applied to the pistons which could cause the shearing of shear pins holding the packer in unset position which would prematurely set the packer.

Retrievable well bore packer with landing nipple

Alternative packer setting method

Fluid setting pressure is delivered to a hydraulically set well packer through an external conduit (28) strapped to the exterior of a well workstring above the packer assembly (26). The continuity of the external conduit is continued past the packer assembly by following a flow channel along the mandrel sleeve (44) thickness. Representatively, the external conduit may serve a primary well function other than packer setting (e.g. well chemical delivery). A calibrated rupture element (68) in the external conduit is disposed to initially obstruct external conduit flow past the packer element. Consequently, fluid pressure transferred down the external conduit is first channeled to the packer setting pressure chamber. After setting, the fluid pressure in the external conduit is increased to rupture the calibrated element. When the external conduit flow channel is opened by rupture of the calibrated element, and the additional well service function may be accomplished.

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Packer for alternate flow channel gravel packing and method for completing a wellbore

Packer for alternate flow channel gravel packing and method for completing a wellbore

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Method for setting a packer within a wellbore

Method for setting a packer within a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting the packer to a tubular body, running the packer and connected tubular body into the wellbore, running a setting tool into the inner mandrel of the packer, pulling the setting tool to mechanically shift a release sleeve from a retained position along the inner mandrel of the packer, thereby releasing the piston housing for axial movement; and communicating hydrostatic pressure to the piston housing through the one or more flow ports, thereby axially moving the released piston housing and actuating the sealing element against the surrounding wellbore.

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Filtro para filtracion con grava de canal de flujo alternativo y metodo para completar un sondeo.

Aparato y método para completar un sondeo incluye proporcionar un filtro que tiene un mandril interior, canales de flujo alternativos a lo largo del mandril interior, y un elemento de sellado externo al mandril interior, que incluye conectar el filtro al cuerpo tubular, después meter el filtro y el cuerpo tubular conectado en el sondeo. En un aspecto, el filtro y el cuerpo tubular conectado pueden colocarse a lo largo de una porción de pozo no revestido del sondeo. El cuerpo tubular puede ser un tamiz de arena, con el tamiz de arena comprendiendo una tubería base, un medio de filtro circundante, y canales de flujo alternativos. El método incluye fraguar un filtro e inyectar una lechada de grava en una región anular formada entre el cuerpo tubular y el sondeo circundante, y después inyectar adicionalmente la lechada de grava a través de los canales de flujo alternativos para permitir que la lechada de grava desvíe por lo menos parcialmente el elemento de sellado del filtro.

用于替代流动通道砾石充填的封隔器和用于完成井筒的方法

用于完成井筒的设备和方法，其包括提供具有内心轴、沿内心轴的替代流动通道以及内心轴外部的密封元件的封隔器，包括将封隔器连接至管状体，随后将封隔器和连接的管状体下入井筒。在一方面，封隔器和连接的管状体可沿井筒的裸眼井部分被放置。管状体可以为砂滤器，砂滤器包括中心管、周围过滤介质和替代流动通道。该方法包括坐封封隔器并将砾石砂浆注入在管状体和周围井筒之间形成的环形区域，并且随后进一步通过替代流动通道注入砾石砂浆，以允许砾石砂浆至少部分地绕过封隔器的密封元件。

Packer for alternate flow channel gravel packing and method for completing a wellbore

Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Sand screen completion

A sand screen having a plurality of sintered, substantially spherical plastic members covering a perforated mandrel is releasably suspended from a packer mandrel by a locking mandrel and a landing nipple. The sand screen and locking mandrel are retrievable with the assistance of a running tool which is insertable into the bore of the locking mandrel. According to this arrangement, the sand screen can be removed and replaced without retrieving the packer or the production tubing. In one embodiment, the sand screen is enclosed within the bore of a sliding side valve. The sliding side valve can be opened and closed as desired for selectively admitting production from various producing zones, or for isolation of a damaged screen. In another embodiment, an auxiliary sand screen having a plurality of sintered, substantially spherical plastic members covering a perforated mandrel is inserted into the bore of a primary screen, for example, a conventional wire-wrap sand screen. The auxiliary sand screen is thus interposed in the flow path for screening out sand fines which may be conducted through the wire-wrap screen because of screen damage caused by corrosion or sand erosion.

Release/anti-preset mechanism for down-hole tools

This invention relates to a release/anti-preset mechanism for retrieving a down-hole tool and for preventing premature actuation of the tool during insertion thereof into a subterranean well-bore. Release mechanisms for retrieving down-hole tools are known and can be divided into three main types: shear release systems, conventional wireline/coil tubing/drill pipe (WL, CT, DP) actuated systems and hydraulically activated systems. Known mechanisms suffer from a number of problems. Accordingly the present invention provides a retrievable down-hole tool (5) having a release/anti-preset mechanism comprising first and second members (10, 15) radially releasably engagable by a third member (20) which controls radial deflection of one of the first or second members (10, 15).

Activator for drill

Ball seat for high pressure and high temperature

Группа изобретений относится к горному делу и может быть применена при бурении и заканчивания скважин. Изолирующее устройство для пробки разрыва пласта содержит шаровое седло, снабженное посадочной поверхностью, и шар, выполненный с возможностью контакта с посадочной поверхностью. Профиль посадочной поверхности выполнен куполовидным, при этом первая часть профиля имеет радиус кривизны, который соответствует радиусу кривизны профиля шара, а вторая часть имеет радиус кривизны больший, чем радиус кривизны первой части. Также раскрыты пробка разрыва и способ изоляции зон продуктивного пласта с использованием изолирующего устройства. Технический результат заключается в повышении герметизации изолирующего устройства. 3 н. и 8 з.п. ф-лы, 49 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2 543 011 C2 (51) МПК E21B 34/06 (2006.01) F16K 13/10 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ (21)(22) Заявка: ИЗОБРЕТЕНИЯ К ПАТЕНТУ 2012149954/03, 21.04.2011 (24) Дата начала отсчета срока действия патента: 21.04.2011 (72) Автор(ы): ШКУРТИ Пиро (US), ВУЛФ Джон К. (US) (73) Патентообладатель(и): СМИТ ИНТЕРНЭШНЛ, ИНК. (US) Приоритет(ы): (30) Конвенционный приоритет: (43) Дата публикации заявки: 27.05.2014 Бюл. № 15 R U 23.04.2010 US 61/327,509 (45) Опубликовано: 27.02.2015 Бюл. № 6 2007169935 A1, 26.07.2007. US 2007074873 A1, 05.04.2007. RU 62155 U1, 27.03.2007. US 2009159289 A1, 25.06.2009 (85) Дата начала рассмотрения заявки PCT на национальной фазе: 23.11.2012 2 5 4 3 0 1 1 (56) Список документов, цитированных в отчете о поиске: US 2009044946 A1, 19.02.2009. US (86) Заявка PCT: 2 5 4 3 0 1 1 R U C 2 C 2 US 2011/033487 (21.04.2011) (87) Публикация заявки PCT: WO 2011/133810 (27.10.2011) Адрес для переписки: 129090, Москва, ул. Б. Спасская, 25, строение 3, ООО "Юридическая фирма Городисский и Партнеры" (54) ШАРОВОЕ СЕДЛО ДЛЯ ВЫСОКОГО ДАВЛЕНИЯ И ВЫСОКОЙ ТЕМПЕРАТУРЫ (57) Реферат: Группа изобретений относится к горному делу который соответствует радиусу ...

Methods and systems for subterranean multilateral well drilling and completion

Improved methods and systems for creating a multilateral well and improved multilateral well structures. In one aspect of the present invention, the method comprises the steps of: (1) setting a diverter at a prescribed position and a prescribed orientation in a main well flow conductor located within a main wellbore, (2) boring through a sidewall of the main well flow conductor and into a material surrounding the main well flow conductor, the boring creating a window having a particular shape in the sidewall, the orientation of the diverter determining a lateral position of the window in the main well flow conductor, a lateral wellbore thereby being formed in the material and extending from the main wellbore, (3) lining the lateral wellbore with a liner, the liner having an interface end, the interface end adapted to contact a periphery of the window in the sidewall and (4) cementing the liner in place within the lateral wellbore, the step of cementing creating a pressure-bearing seal between the periphery of the window and the interface end of the liner. The method allows multiple lateral wellbores to be joined to the main wellbore and provides for connectivity among main and lateral wellbores, pressure-bearing sealing of joints to allow selective isolation of one or more wellbores or portions thereof and subsequent wellbore access for rework or other purposes.

Setting and unsetting a production packer

A packer assembly includes a tubing string disposed in a wellbore and a packer releasably coupled to the tubing string. The packer includes a housing releasably coupled to the tubing string, a packer slip, a flexible sealing element, a piston coupled to the housing, a locking member, and a mandrel disposed inside the housing. The piston moves to activate the packer slip and the flexible sealing element to set the packer on a wall of the wellbore. The locking member engages the piston to constrain movement of the piston to keep the packer set on the wall of the wellbore. The mandrel connects to the tubing string when the tubing string is released from the housing. The locking member is collapsible to disengage the piston to unset the packer slip and the flexible sealing element responsive to shear force applied by the mandrel to the locking member.

Method of suspending, completing and working over a well

本发明的各种方法是在井(10)中分别设置第一阻挡层和第二阻挡层(26)和(30)，以便在井暂停、完井和/或修井作业期间实现井控。当完井管柱安装在井(10)中时，各阻挡层位于完井井最下端的深度下方。由于每一个阻挡层的位置均未高出井孔，故两个阻挡层在停井、完井和修井作业期间均保持在位，从而无需再另外使用防喷器组来进行井控，这使得钻井时间大大节省，从而有效地降低了井的建设成本。

Ultra-short type removable hydraulic packer

本发明涉及一种超短型可取式液压封隔器，属油气井井下作业工具领域。该封隔器包括中心管、上接头和下接头，上接头和下接头之间的中心管中间部位通过导环安装有胶筒和下椎体；上接头一侧的中心管上通过连接环装有上移环和下移环，胶筒和下接头之间的中心管上通过缸套装有上活塞，上活塞与下接头之间的中心管上设置有打压孔。该封隔器的中心管为一体式中心管，增强了封隔器在生产过程中的可靠性和整体性的强度。解决了现有封隔器由于结构复杂，致使加工、组装、测试、使用以及运输都很不方便，且只能承受单向的载荷的问题。该封隔器大大简化了封隔器的整体结构，降低了封隔器的成本，特别适用于油气井的钻井、固井、增产措施作业使用。

Breakway obturator for downhole tools

An obturator for actuating a downhole tool having a central bore. The obturator comprising a body of a size and shape to pass through the central bore of the tool and an engagement member releasably attached to the exterior of the tool body, the engagement member being of a size and shape to engage and actuate the tool.

Well wedge device

Группа изобретений относится к скважинному клиновому устройству, узлу, способу управления работой скажинного клинового устройства. Техническим результатом является повышение эффективности крепления устройства. Скважинное клиновое устройство содержит радиально раздвижной клиновой узел, содержащий основное клиновое устройство и вспомогательное клиновое устройство. Основное клиновое устройство образует первую взаимодействующую со стенкой поверхность. Вспомогательное клиновое устройство образует вторую взаимодействующую со стенкой поверхность. В первой фазе работы основное и вспомогательное клиновые устройства можно одновременно радиально раздвигать из сложенной конфигурации к и/или в первую раздвинутую конфигурацию. В последующей второй фазе работы вспомогательное клиновое устройство можно радиально раздвигать относительно основного клинового устройства ко и/или во вторую раздвинутую конфигурацию. Первая и вторая взаимодействующие со стенкой поверхности содержат проникающие элементы и взаимодействующие элементы. Узел содержит трубу, установленную со скважинным клиновым устройством. 3 н. и 26 з.п. ф-лы, 8 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2 735 594 C2 (51) МПК E21B 23/01 (2006.01) E21B 33/12 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ (52) СПК E21B 23/01 (2020.02); E21B 33/12 (2020.02) (21)(22) Заявка: 2018136110, 14.03.2017 (24) Дата начала отсчета срока действия патента: Дата регистрации: (73) Патентообладатель(и): ВЕЗЕРФОРД Ю.Кей. ЛИМИТЕД (GB) 05.11.2020 15.03.2016 GB 1604389.5 (43) Дата публикации заявки: 15.04.2020 Бюл. № 11 (56) Список документов, цитированных в отчете о поиске: US 6769491 B2, 03.08.2004. RU 2478776 C1, 10.04.2013. RU 113785 U1, 27.02.2012. RU 159875 U1, 20.02.2016. RU 2189430 C1, 20.09.2002. US 2010/186947 A1, 29.07.2010. (45) Опубликовано: 05.11.2020 Бюл. № 31 (85) Дата начала рассмотрения заявки PCT на национальной фазе: 15.10.2018 2 7 3 5 5 9 4 Приоритет(ы): (30) Конвенционный ...

Secondary lock for a downhole tool

A downhole tool includes a mandrel, a sealing element disposed around the mandrel, an upper cone disposed above the sealing element and a lower cone disposed below the sealing element, an upper slip assembly disposed above the upper cone and a lower slip assembly disposed below the sealing element, at least one lock ring configured to maintain energization of the sealing element when the downhole tool is set, and a secondary lock that couple the upper cone with the at least one lock ring. A method of increasing pack-off force of a downhole tool includes setting the downhole tool and energizing further the sealing element by applying a differential pressure to the downhole tool. A method of retrofitting a downhole tool includes providing a secondary lock disposed around a mandrel, the secondary lock including at least one arm having an axial portion extending downwardly therefrom and a threaded portion, and assembling the secondary lock to the downhole tool, the assembling including engaging the threaded portion of the secondary lock to a threaded surface of an upper cone disposed around the mandrel of the downhole tool.

Hydro inflatable packer

FIELD: oil and gas industry. SUBSTANCE: invention relates to oil industry and can be used for rapid disconnection of well shaft during repair and preventive works in well. Packer includes a shaft with cushioning on it elastic collar element lowered into a casing string. This element is made with an air inflatable cavity. It is fixed on the shaft with the help of upper and lower stops covering ends of the sealing element. Above upper stop concentrically arranged on barrel housing is installed. Housing is fixed by split ring from shift upwards. There is a filter forming a cavity with the housing for pure hydraulic fluid supplied through the filter from above-packer space of the well. In housing there installed is electrically driven pump for injection of pure hydraulic liquid into hydraulically inflated cavity through radial channel equipped with check valve, and a longitudinal channel provided with a check valve through a cavity made in the housing, with a sensor for measuring pressure in the pressurizing cavity. There is a controlled discharge valve for releasing excess fluid pressure from the hydraulically inflated cavity through the second longitudinal and radial channels. On top of the filter there is a measuring module with a liquid pressure sensor in the above-packer space. Under the lower stop there installed is the second housing fixed by the collar on the shaft from the downward displacement, equipped with the second measuring module with the liquid pressure sensor in the below-packer space of the well. In this space there is a second controlled drain valve for releasing excess fluid pressure from the hydraulic inflatable cavity into the sub-packer space through the longitudinal channel made at the bottom of the sealing element and in the lower support, and a radial channel communicating the drain valve with the pressurized cavity. Longitudinal channels are additionally equipped with branch pipes tightly connecting the sealing element with stops. Electric ...

Pressure balanced setting tool

A system including a downhole device coupled to a pressure balanced setting tool. The setting tool may be pressure balanced to lock a setting piston in place as the system is deployed into a well. That is, in spite of downhole well pressures, no substantial differential may emerge between the setting piston and the annular space of the well adjacent the system. Thus, the setting piston may remain locked in place until triggered for setting. This may include breaching a rupture disc of another piston to disrupt hydraulic communication between the setting piston and the annular space. This allows subsequent triggering, for example through another breach of a rupture disc defining a volumetric chamber, to take place in a manner that allows stroking of the setting piston. In this way, the setting tool may be utilized to achieve setting of the downhole device.

Interventionless set packer and setting method for same

A packer ( 80 ) for establishing sealing engagement with a surface disposed in a wellbore includes a packer mandrel ( 90 ) and a seal assembly ( 100, 102, 104 ) slidably disposed about the packer mandrel ( 90 ). The seal assembly ( 100, 102, 104 ) has a running position and a radially expanded sealing position. A piston ( 122 ) is slidably disposed about the packer mandrel ( 90 ) and operably associated with the seal assembly ( 100, 102, 104 ). A release assembly 145 is disposed about the packer mandrel ( 90 ) and is releasably coupled to the piston ( 122 ) such that actuation of the release assembly ( 145 ) decouples the release assembly ( 145 ) from the piston ( 122 ) allowing the piston ( 122 ) to shift longitudinally relative to the packer mandrel ( 90 ) to operate the seal assembly ( 100, 102, 104 ) from the running position to the radially expanded sealing position, thereby setting the packer ( 80 ).

Interventionless set packer and setting method for same

A packer ( 80 ) for establishing sealing engagement with a surface disposed in a wellbore includes a packer mandrel ( 90 ) and a seal assembly ( 100, 102, 104 ) slidably disposed about the packer mandrel ( 90 ). The seal assembly ( 100, 102, 104 ) has a running position and a radially expanded sealing position. A piston ( 122 ) is slidably disposed about the packer mandrel ( 90 ) and operably associated with the seal assembly ( 100, 102, 104 ). A collet assembly 145 is disposed about the packer mandrel ( 90 ) and is releasably coupled to the piston ( 122 ) such that radially inwardly shifting at least portion of the collet assembly ( 145 ) decouples the collet assembly ( 145 ) from the piston ( 122 ) allowing the piston ( 122 ) to shift longitudinally relative to the packer mandrel ( 90 ) which operates the seal assembly ( 100, 102, 104 ) from the running position to the radially expanded sealing position, thereby setting the packer ( 80 ).

Communication conduit in a well tool

An improved apparatus for transmitting signals through a well tool is provided. In a broad aspect, the present invention is a communication conduit in a well tool comprising: a cylindrical mandrel having a longitudinal bore therethrough, an inner diameter, an outer diameter, and an outside circumference; a well tool attached to the outside circumference of the cylindrical mandrel; and at least one signal transmitting passageway positioned in the mandrel between the inner diameter and the outer diameter. In a specific embodiment, the well tool may be a packer. The at least one signal transmitting passageway may be used as a carrier for electrical or fiber optic conductors, or it may be a pressure retaining member whereby pressurized hydraulic fluid may be passed through to a device below the well tool without interruption.