Abstract: A graphics card heat-dissipating device includes: a main body, a support seat, and a fixed element. The main body has a first heat-dissipating portion and a second heat-dissipating portion, and the first heat-dissipating portion has a first opening and the second heat-dissipating portion has a second opening. The support seat is used for supporting a chip, and the support seat has a third opening. The fixed element is fixed on the first heat-dissipating portion by passing through the second opening, the third opening and the first opening in sequence for attaching the chip on the first heat-dissipating portion. Therefore, the heat convection function and the heat-dissipating efficiency are increased.

Abstract: Embodiments of the present invention provide a method and apparatus for flow testing multiple zones in a single trip. In one embodiment, a method of flow testing multiple zones in a wellbore includes lowering a tool string into the wellbore. The tool string includes an inflatable packer or plug and an electric pump. The method further includes operating the pump, thereby inflating the packer or plug and isolating a first zone from one or more other zones; monitoring flow from the first zone; deflating the packer or plug; moving the tool string in the wellbore; and operating the pump, thereby inflating the packer or plug and isolating a second zone from one or more other zones; and monitoring flow from the second zone. The zones are monitored in one trip.

Abstract: A dynamic inflatable sealing device for maintaining the pressure within an inflatable element at least substantially equal to the pressure in the annulus to maintain the inflatable element in a sealing position. The dynamic sealing device includes an inflatable element forming an internal chamber, the inflatable element expandable to sealing engagement with a wall, and a dynamic valve mechanism in operational connection between the internal chamber and exterior of the internal chamber substantially communicating the pressure external of the inflatable element to the internal chamber.

Abstract: An isolation assembly for use with coiled tubing is described. The isolation assembly has a check valve for providing selective fluid communication through from the coiled tubing, through the isolation assembly, and into a downhole tool, such a straddle packer. The isolation assembly includes a shuttle moveable within a housing, and plurality of ports to selectively provide fluid communication from within the isolation assembly below the check valve, through the ports, and into the annulus, thus allowing selective surface-controlled equalization of downhole equipment. Also described is a bottom hole assembly including the isolation assembly. An improved method of fracing a formation includes providing a check valve, thus improving the life of the coiled tubing and the safety of the operation, and reducing the time to perform a given downhole operation.

Abstract: A device for injecting a fluid into an earth formation surrounding a wellbore, comprising a body suitable to be arranged in the wellbore and being provided with means for connecting the body to a tubing, a fluid chamber for storage of said fluid, and a pair of inflatable packers arranged to isolate a portion of the wellbore between the packers from the remainder of the wellbore upon inflation of the packers, the body further being provided with an outlet port located between the packers for flow of fluid from the fluid chamber to outside the device, means for inflating the packers upon the occurrence of a primary fluid pressure in the tubing, and means for ejecting fluid from the fluid chamber via the outlet port to outside the device upon the occurrence of a secondary fluid pressure in the tubing, wherein the secondary fluid pressure is higher than the primary fluid pressure.

Abstract: A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in in a pressure tight condition and later is needed to be in an open-port condition.

Abstract: A check enhancer for use in a well comprises a housing portion and an injector portion disposed in the housing portion. The housing portion includes an outer body defining a fluid cavity therein with a plurality of body ports in communication with the fluid cavity. The injector portion includes a check valve and a dispersement nipple in communication therewith. The check valve is connected to the outer body, and the dispersement nipple extends into the fluid cavity. The check valve allows fluid flow from the tubing through nipple ports defined in the dispersement nipple. The nipple ports are longitudinally spaced from the body ports so that the fluid cavity remains substantially filled with fluid with the dispersement nipple substantially submerged within the fluid.

Abstract: A technique to facilitate deployment of power cable and at least one capillary tube through a wellbore tool, such as a packer. The technique allows both the power cable and the at least one capillary tube to extend through a single pass-through opening in the wellbore tool.

Abstract: A collar for injecting fluid, such as a formation treating fluid, into a wellbore, and a method for using same. The collar is disposed between the upper and lower packing elements of a pack-off system during the treatment of an area of interest within a wellbore. The collar first comprises an inner mandrel running essentially the length of the collar. The inner bore of the collar is in fluid communication with the annular region between the collar and the surrounding perforated casing by a set of actuation ports. A second set of ports, known as frac ports, is disposed within the mandrel. In accordance with one aspect of the invention, the collar further comprises a tubular case which substantially seals the frac ports in a first position, and slidably moves along the outer surface of the mandrel in order to expose the frac ports in a second position. In operation, the upper and lower packing elements are set at a first fluid pressure level.

Abstract: A check enhancer for use in a well comprises an outer housing portion and an inner injector portion disposed in the housing portion. The housing portion includes an outer body defining a fluid cavity therein with a plurality of body ports in communication with the fluid cavity and an adapter which slidably receives a portion of a length of tubing therethrough. A tubing fitting connects the tubing to the adapter. The injector portion includes a check valve and a dispersement nipple attached thereto. The check valve is connected to the tubing in the fluid cavity by another tubing fitting, and the check valve allows fluid flow from the tubing through nipple ports defined in the dispersement nipple. The nipple ports are longitudinally spaced from the body ports so that the fluid cavity remains substantially filled with fluid with the dispersement nipple substantially submerged within the fluid.

Abstract: The present invention, therefore, discloses in certain, but not necessarily all, embodiments a method for reclaiming a borehole extending from an earth surface into the earth, part of which borehole is in a lost circulation zone, the method including closing off the borehole to fluid flow above the lost circulation zone by installing a packer system with an inflatable packer element, a plurality of ribs mounted around the inflatable packer element, and a valve apparatus in the borehole above the lost circulation zone, the packer system made of drillable material, inflating the inflatable packer element with cement, and allowing the cement to set so that the inflatable packer and the valve apparatus effectively seal off the borehole to fluid flow.

Abstract: A collar for injecting fluid, such as a formation treating fluid, into a wellbore, and a method for using same. The collar is disposed between the upper and lower packing elements of a pack-off system during the treatment of an area of interest within a wellbore. The collar first comprises an inner mandrel running essentially the length of the collar. The inner bore of the collar is in fluid communication with the annular region between the collar and the surrounding perforated casing by a set of actuation ports. A second set of ports, known as frac ports, is disposed within the mandrel. In accordance with one aspect of the invention, the collar further comprises a tubular case which substantially seals the frac ports in a first position, and slidably moves along the outer surface of the mandrel in order to expose the frac ports in a second position. In operation, the upper and lower packing elements are set at a first fluid pressure level.

Abstract: The present invention relates to straddle packer systems and methods of using them for downhole isolation of zones for fracturing treatment. More specifically, the system includes upper and lower seal systems having resiliently flexible sealing elements hydraulically and operatively connected to one another which are responsive to an increase in hydraulic pressure for setting the sealing elements at a first hydraulic pressure threshold. Additionally, the system includes a control system hydraulically and operatively connected between the upper and lower packer systems which is responsive to an increase in hydraulic pressure at a second hydraulic pressure threshold higher for activating a pressure switch system within the control system for opening at least one frac valve in the control system.

Abstract: A tubing plug is adapted for insertion into a tubing string for sealing the tubing string. The tubing plug is comprised of a housing having an outer surface, wherein the housing is adapted for insertion in the tubing string such that an annulus is defined between the tubing string and the outer surface of the housing and wherein the housing defines a fluid passage therethrough, the fluid passage having an upper end and a lower end. A sealing mechanism is associated with the housing for sealing the annulus and a two-way fluid bypass is provided for selectively permitting a flow of a fluid across the sealing mechanism. Finally, a one-way valve is located at the lower end of the fluid passage for selectively permitting a flow of a fluid in a first direction from the upper end to the lower end of the fluid passage and for preventing a flow of a fluid in a second direction from the lower end to the upper end of the fluid passage.

Abstract: A tool string, such as one used for performing fracturing operations or other types of operations, includes a valve, a valve operator, and a sealing assembly that in one arrangement includes packers to define a sealed zone. The tool string is carried on a tubing, through which fluid flow may be pumped to the sealed zone. The valve operator is actuated in response to fluid flow above a predetermined flow rate. When the flow rate at greater than the predetermined flow rate does not exist, the valve operator remains in a first position that corresponds to the valve being open. However, in response to a fluid flow rate at greater than the predetermined flow rate, the valve operator is actuated to a second position to close the valve.

Abstract: A tubular body or mandrel incorporated into a string of tubular pipe, on which first and second swab cups and a casing scraper are mounted, is run into a cased earth borehole to displace a first fluid in the borehole, usually a drilling fluid, with a second fluid, usually either a completion fluid or a workover fluid. In a first embodiment, reverse circulation, in which the second fluid is pumped into the borehole annulus above the swab cups, and in which the first fluid is thereby pumped back towards the earth's surface through the interior of the string of tubular pipe, causes displacement of the first fluid merely by lowering the string of pipe while pumping the second fluid into the borehole annulus. In a second embodiment, using normal circulation, the first fluid is pumped from the earth's surface downwardly through the interior of the string of tubular pipe into the borehole annulus between the pair of swab cups.

Abstract: A pack-off system for packing off an area of interest in a wellbore, the pack-off system comprising a body, two spaced-apart selectively settable packing elements on the body for sealing off the area of interest, selectively actuatable setting apparatus connected to the body for selectively setting the two spaced-apart selectively settable packing elements, the selectively actuatable setting apparatus actuatable by fluid under pressure introduced into the pack-off system. A method for packing off an area of interest in a wellbore, the method including installing a pack-off system as described herein in the wellbore to pack-off the area of interest. Such a method may also include flowing treatment fluid from the pack-off system to an area of interest in an earth formation and/or adjacent a wellbore in the earth.

Abstract: A downhole adjustable choke includes a choke body which is adapted to be lowered into a borehole. The choke body has a bore and an orifice connected to the bore. A sleeve is disposed inside the bore of the choke body. The sleeve has an orifice which is aligned with the orifice in the choke body. An actuator is coupled to move a flow plug inside the sleeve so that the flow area of the orifice in the sleeve is adjustable.

Abstract: A plug for a wellbore including a plug element adapted to traverse the wellbore and a reservoir coupled to the plug element. The reservoir is hydraulically coupled to an annular space between a wall of the wellbore and an exterior surface of the plug element. The reservoir carries a filler material within. Extrusion of the filler material from the reservoir causes the filler material to fill the annular space so as to bind the plug element within the wall of the wellbore. One embodiment of the plug an anti-rotation element coupled to the plug element. The plug element can be coupled to drill pipe by opposite-hand thread whereby engagement of the anti-rotation element enables decoupling of the plug from the drill pipe by normal-direction rotation of the drill pipe.

Abstract: An inflatable packer with a packer body, an inflatable bladder mounted around the packer body, a bladder support mounted around the inflatable bladder, the packer body, the inflatable bladder and the bladder support made of drillable material. A method for reclaiming a borehole extending from an earth surface into the earth, part of which is in a lost circulation zone, the method including closing off the borehole to fluid flow above the lost circulation zone by installing a packer system with an inflatable packer element and a valve apparatus in the borehole above the lost circulation zone, inflating the inflatable packer element with cement, and allowing the cement to set so that the inflatable packer and the valve apparatus effectively seal off the borehole to fluid flow.

Abstract: The present invention relates to a drill string diverter apparatus for reducing surge pressure when lowering a liner into a partially cased wellbore. The diverter apparatus is connected in a pipe string above a liner being lowered into a wellbore. The diverter apparatus comprises a tubular housing with ports defined therethrough to communicate and redirect fluids received in the liner to the annulus between the diverter apparatus and casing previously set in the wellbore. The diverter apparatus has an open position whereby the ports are open and communication is established and a closed position whereby flow through the ports is prevented. A sliding sleeve is disposed about an outer surface of the tubular housing and engages the casing. The sleeve moves vertically relative to the tubular housing once the diverter apparatus has been lowered into the casing to selectively open and close the flow ports. A J-slot means is provided for locking the diverter apparatus in its closed position.

Abstract: A repositionable apparatus for perforating and gravel packing an underground well uses gravity or other means to reposition the apparatus instead of a conventional wireline or work string attached to a rig. Perforating and packing can be accomplished without a rig after the apparatus is initially placed and set in the well. One embodiment of the inventive apparatus uses a perforating gun assembly, a connected ported sub above the gun assembly, a translating annulus packer above the ported sub, a circumferential screen located above the packer, blank pipe connected above the screen, an openable port above the blank tubular pipe, and a second translating annulus packer attached to the blank tubular.

Abstract: The present invention relates to a drill string diverter apparatus for reducing surge pressure when lowering a liner into a partially cased wellbore. The diverter apparatus is connected in a pipe string above a liner being lowered into a wellbore. The diverter apparatus includes a tubular housing with ports defined therethrough to communicate and redirect fluids received in the liner to the annulus between the diverter apparatus and casing previously set in the wellbore. The diverter apparatus has an open position whereby the ports are open and communication is established and a closed position whereby flow through the ports is prevented. A sliding sleeve is disposed about an outer surface of the tubular housing and engages the casing. The sleeve moves vertically relative to the tubular housing once the diverter apparatus has been lowered into the casing to selectively open and close the flow ports. A J-slot means is provided for locking the diverter apparatus in its closed position.

Abstract: The invention relates to a well casing 11 including at least two casing lengths 12, 13, 14, 15, 16 with a first casing section 12 having and outside diameter OD12 and an inside diameter ID12 being fitted and cemented in position extending downwardly from the top of the well. The remaining sections are installed subsequently each subsequent casing section 13, 14, 15, 16 having an outside diameter OD13, OD14, OD15, OD16 and an inside diameter ID13, ID14, ID15, ID16 and the diametrical difference D1, D2, D3, D4, D5 between the outside diameter OD13, OD14, OD15, OD16 of the sections 13, 14, 15, 16 being less that the internal diameter ID12, ID13, ID14, ID15 of the corresponding fitted sections 12, 13, 14, 15 being an amount which is just sufficient for the subsequent sections 13, 14, 15, 16 to pass down through the internal bore of the corresponding fitted section 12, 13, 14, 15.

Abstract: The liner packer assembly and method includes a liner packer having a tubular body with an aperture for the flow of wellbore fluids. A packing element is movably disposed on the tubular body between an open position on one side of the aperture for allowing wellbore fluids to flow through the aperture to a closed position on the other side of the aperture for closing flow through the aperture and for packing off the annulus between the packer and outer casing. During the cementing operation, drilling fluids and cement are allowed to flow through the annular area formed by the packer and outer casing and also flow through the aperture in the tubular body of the packer and up the inside diameter or inner annular area formed by the packer and inner tubular string. The inner and outer annular areas around packer approximately the flow area below the packer between the inner tubular string and the outer casing.

Abstract: A resettable well stimulation tool is lowerable into a well bore on a length of tubing through which pressurized fluid may be forced into the tool to inflate a packer portion carried by the tool and then discharge a stimulation fluid into a portion of the well bore sealed off by the packer portion. During the inflation cycle of the tool pressurized fluid is forced downwardly into an annular tool body inflation chamber that communicates with an inflatable packer carried by the tool body. A perforated tube member coaxially carried in the inflation chamber serves to vertically distribute the inflation pressure along the length of the packer and assure its even inflation. In a straddle packer embodiment of the tool inflation and stimulation passages extend internally through the tool and are sealingly separated by an internal crossover structure, with the inflation passage being in communication with upper and lower packer members.

Abstract: The present invention provides a tool and methods of placing a treatment fluid in a subterranean formation penetrated by a well bore by way of selected perforations extending from casing cemented in the well bore into the formation. The fluid placement tool includes a fluid flow passageway extending therethrough, at least one resilient self expandable cup type packer attached thereto and a valve disposed in the fluid flow passageway which closes the passageway when a closing plug is dropped into the tool. The placement tool is capable of releasing the cup type packer whereby it provides a seal between the tool and the casing when a first predetermined fluid pressure is applied to the tool after a closing plug is dropped therein and opening the fluid flow passageway whereby the treatment fluid is discharged from the tool below the packer when the fluid pressure is increased to a second predetermined fluid pressure. Methods of using the tool are also provided.

Abstract: A straddle tool is disclosed which ensures sequential setting of the packing elements through the use of lost motion mechanisms. Once the lower pack-off has been set, the upper one is set and an internal valve is opened to allow flow through the tool to actuate a downhole tool, such as an inflatable packer. An anchor prevents actuation of the pack-off tool unless it is extended into a profile for support of the tool. Inadvertent settings of the pack-off tool are prevented, such as in oversized casing where the anchors are already fully extended, by virtue of a distance-sensing mechanism on the tool. When a large distance is sensed by one or more sensors, the mandrel is locked to the setting collars, preventing relative movement which could set the pack-off elements.

Abstract: A pressure limit valve for well tools where a valve member is moveable between a first closed portion, an open position and a second closed position. A spring for closing the valve is separated from a locking chamber which contains locking elements. The locking elements are located in a locking chamber and are held deactivated by a release sleeve which separates from the valve member in an open position. When the valve moves to the second closed position it is locked by engagement of the locking elements with a stop shoulder. In use between closely coupled inflatable packers, the valve prevents trapped pressure between the packers from affecting operation of the packer valve.

Abstract: An apparatus and method for controlling the pressure at which a fluid is introduced into a well penetrating a subterranean formation. The apparatus comprises a blow out sub having a sealed chamber between two plugs. The chamber is filled with a fluid at a known pressure. Thus, the pressure required to release the first plug is independent of the pressure in the well below the sub. The sub is attached to a tubular and positioned within the well. The first plug is then released upon application of a predetermined pressure fluid pressure, and the second plug is released upon application of a lesser pressure. The blow out sub may additionally comprise a tube forming a channel through the first plug, the chamber, and the second plug, with a means for controlling fluid flow through the channel. A first fluid may be introduced into the well via the channel prior to releasing the first plug.

Abstract: A downhole tool apparatus and methods of drilling the apparatus. The apparatus may include, but is not limited to, packers and bridge plugs utilizing non-metallic components. The non-metallic components may include but are not limited to the center mandrel having an unmachined, molded central opening therethrough. In a preferred embodiment, a sliding valve is disposed on an outer surface of the center mandrel for opening and closing a valve port. An overshot is used to selectively actuate the sliding valve. Methods of installation and drilling out of the apparatus are also disclosed.

Abstract: An inflatable stimulation tool designed to be deployed by coil tubing having a shuttle valve which reciprocates within the bore of a tubular mandrel. The shuttle valve, in cooperation with a reciprocally movable outer mandrel which is disposed about an inner mandrel, opens and closes various ports in the device to alternately seal and unseal the inflatable packer element. The shuttle valve also operates to open and close a flow passage through the inner mandrel to permit the passage of various stimulation fluids through the tool and into the well bore.Upon deflation of the inflatable packing means, which leaves the packing means in a somewhat distended state, the element is urged to its original close relationship with the mandrel by a return spring which cooperates with the lower tool structure to which one end of the rubber packing element is clamped to longitudinally stretch the element.

Abstract: A resettable downhole packer is provided. Circulation from the surface creates a backpressure behind the packing element that expands the packing element into contact with the wellbore or casing. The tool may be shifted to trap pressure behind the element to retain it in contact with the wellbore or casing while, at the same time permitting flow through the packing element for procedures such as injection or stimulation. The tool incorporates a release mechanism to facilitate retrieval of the tubing string if, for any reason, the tool becomes stuck. Provisions are incorporated into the design to maintain the packing element in a retracted position for the running in and removal to avoid damage to the packing element.

Abstract: An improved sealing is provided for repairing a breach of down hole casing integrity, while maintaining substantially unrestricted annular fluid communication through the length of the well bore which comprises a casing sleeve supported on a tubing string for providing an alternate liquid or gas flow route about the tubing string at the defective portion of the casing. The casing sleeve is disposed between and connected to a first and second seal support housing assembly, each of which has an internal bore and a retaining end portion dimensioned to prevent a tubing collar of the tubing string from passing therethrough. Resilient casing engaging members are supported on each of the first and second seal support housing assemblies such that the resilient casing engaging members provide an effective seal between the first and second seal support housing assemblies and an adjacently disposed internal wall of the casing.

Abstract: A packer apparatus, particularly a cup type casing packer shoe, includes a pressure-actuated closing sleeve and pressure-actuated pumpout seats. An upper pumpout seat moves with the closing sleeve in response to a first pressure so that the closing sleeve closes ports through which fluid is communicated to an annulus outside the apparatus. Both the upper pumpout seat and a lower pumpout seat and any intervening fluid are pumped out of the apparatus in response to a second, higher pressure so that the apparatus communicates with the well below the annulus without a drillout procedure having to be performed through the apparatus or a tubing string in which the apparatus is connected. A related method is also disclosed.

Abstract: Wellbore fluid flow rates and other fluid properties may be measured by a tool which is insertable in the wellbore on the end of a tubing string and includes an instrument section and an inflatable packer disposed on the tool for inflation by conducting pressure fluid down the tubing string to the packer. A control valve disposed on the tool is hydraulically shiftable between first and second positions for conducting fluid from the tubing string to the packer and from the packer to the exterior of the tool. The valve may be actuated by fluid conducted down the tubing string. The tool includes housing parts having respective cavities for conducting wellbore fluid through a flowmeter and for containing instrument circuit enclosures disposed therein. Pressure fluid bypasses the cavities through elongated passages formed in the tool housing parts along or adjacent to the outer periphery of the housing parts. A frangible coupling is interposed in the tool between the packer and the instrument section.

Abstract: A fluid flow control system, assembly and method for wells in which a sliding sleeve valve is connected in a string of well tubing in a wellbore casing. The sliding sleeve valve functions to selectively control the lateral flow of fluid through the assembly into the annulus between the assembly and the wellbore casing. A straddle assembly is locked within the sleeve valve assembly for isolating a lateral flow path. A stinger assembly is provided which receives reeled tubing and is insertable to lock within the straddle assembly to create a flow path between the reeled tubing and exterior of the sleeve valve.

Abstract: A straddle packer apparatus includes a housing having a central opening. The housing has inflation passages, treating fluid passages, and equalizing passages defined therein. Upper and lower longitudinally spaced packers are mounted on the housing on opposite sides of an outlet of the treating fluid passage. An inner mandrel is slidably received in the central opening of the housing. The mandrel has a mandrel bore and has upper and lower inflation ports, upper and lower equalizing ports, and a treating port, all of which communicate with the mandrel bore. A lug and endless J-slot is operably associated with the housing and mandrel for controlling a telescoping position of the mandrel relative to the housing in response to telescoping reciprocation without rotation of the mandrel relative to the housing.

Abstract: A well clean-out tool comprising a ported nipple, thimble, packer cup, packer cup mandrel and an inner mandrel.

Abstract: A pressure packer assembly adapted for positioning in a bore of a gas or oil well, and having a compressible sealing element which when actuated prevents fluid flow from below the compressed sealing element, with the packer assembly including the sealing element, having a lateral opening therethrough so that fracturing fluid passes through such lateral opening in the packer assembly into fracturing contact with the well bore. A notch gun coacting with the packer is also disclosed.

Abstract: Relatively rotatable inner and outer tubular bodies include ports for communicating a well string in which the bodies are connected with the well bore. A seal between the bodies surrounds the port in one of the bodies to control communication between the bodies and well bore when the bodies are rotated to align and misalign the ports. A restrainer engages the well bore to restrain one of the bodies while the other is rotated by the well string and a receptacle with a port between seals that engage the well bore is provided so that a treating fluid placed in the well string may be pumped down while the body ports are open to discharge well string fluid to the well bore and when the treating fluid reaches the bodies, the ports are closed so the treating fluid may be discharged through the receptacle ports into the well bore zone isolated between the seals on the receptacle.

Abstract: An apparatus for placing a filter screen and for packing gravel around the filter screen adjacent a well formation. The apparatus includes a body having a packer portion and a valve portion. The body defines a central passageway therethrough. The valve portion includes a valve mandrel with a valve sleeve slidably positioned therein, and transverse openings in the valve sleeve and valve mandrel are aligned to form a transverse passageway therethrough when the valve is in an open position. A stinger is positionable in the body for closing the central passageway and actuating the valve sleeve between the open and closed positions thereof. When in the open position, the transverse openings in the valve mandrel and valve sleeve are aligned with a transverse opening in the stinger such that fluid communication is provided between a well annulus below the packer portion and the tool string above the apparatus. Collet fingers engage the stinger so that when the stinger is moved from the body, the valve is closed.

Abstract: A method for cementing a casing or a liner traversing earth formations comprising the supplemental injection of cement at a pressure greater than the pore pressure in the earth formations during a cementing operation to enchance the effectiveness of the cement integrity by maintaining hydrostatic pressure in an annulus between the pipe and the borehole at a location where the pore pressure of the earth formations is apt to impair the cement integrity in the annulus thereby preventing annular migration of gas or liquids in the cement seal between the earth formations and a liner or casing.

Abstract: A selective injection packer apparatus includes a housing having a longitudinal housing bore therethrough. A mandrel has a longitudinal mandrel bore therethrough and is slidably disposed in the housing bore. Upper and lower longitudinally spaced compressible packers are disposed about the housing. Upper and lower power pistons are operably associated with the housing and the upper and lower packers, respectively, for longitudinally compressing and radially expanding the upper and lower packers in response to an increase in fluid pressure within the mandrel bore. A power passage is operatively associated with the power pistons for selectively communicating the mandrel bore with the power pistons. An injection passage is operatively associated with the housing and the mandrel for selectively communicating the mandrel bore with an exterior of the housing between the upper and lower packers.

Abstract: A tool (20) for washing the perforated zone of a well casing in an oil or gas well includes a tubular mandrel (24) having a flow passage (26) with means for connecting one end of the mandrel to a drill string (160) and the second end to a flow blocking valve (162). The mandrel (24) has a plurality of apertures (42) through its sidewall. A first and second radially expandable packer (64, 132) completely encircles and is carried on the mandrel at spaced positions. An outer sleeve (100) surrounds the mandrel between the packers and defines an annular chamber (116) between the sleeve and mandrel. The sleeve has apertures (104) therethrough having a combined area less than the combined area of the apertures (42) through the mandrel. First and second annular pistons (74, 100) are carried within the annular chamber (116) having one face communicating with the annular chamber and an opposite face engaging, respectively, the first and second packers.

Abstract: A downhole tool inflatable packer assembly includes an upper packer shoe having a bypass mandrel connected thereto. A packer mandrel adapter has an upper end connected to a lower end of the bypass mandrel. A mandrel cover tube extends downwardly from the packer mandrel adapter. A packer mandrel has an upper portion connected to the packer mandrel adapter. A flow connector and a lower packer adapter are connected in that order below the packer mandrel. A packer flow tube has an upper end received in the bypass mandrel and a lower end received in the flow connector. An inflatable bladder has an upper end connected to the upper packer shoe and a lower end connected to a floating packer shoe which slidably engages the mandrel cover tube. A central flow passage, a packer bypass passage, and an inflation passage are disposed in the packer assembly.

Abstract: A method and apparatus for placing a cement thermal packer is disclosed. The cementing collar of the present invention is assembled into a stream or hot fluid injection string and positioned along the well in the location where the packer is to be placed. Cement material for the packer is pumped down the injection string preceded by a separation plug and followed by a sealing plug. The separation plug seats in the cementing collar to cause the cement to be diverted to the annulus between the well casing and the injection string. The sealing plug seats in the collar while the placed cement sets to form the packer. The internals of the collar are sheared from the collar leaving a smooth injection string to the injection zone of the well.

Abstract: A method and apparatus are disclosed for sequentially treating two vertically separated zones in a well bore, utilizing a packer having a fluid passageway therethrough set between the zones, a pressure shearable plug at the lower end of the packer, and a retrievable fluid plug at the upper end of the packer. Once the packer, with the shear plug on its lower end, is set in the well bore between the two zones, the retrievable plug is placed in the upper end of the packer to isolate the shear plug from well pressure in the upper zone, and the desired treating steps are performed on the upper zone. The retrievable fluid plug is then removed and tubing run to the packer to establish communication with the shearable fluid plug. The shearable plug permits static pressure testing of the tubing string and seals before communication is established with the lower zone, and then may be removed by elevating fluid pressure to sufficiently shear the plug.

Abstract: A unit adapted to be attached to a large number of similar units to form an apparatus to permit the taking of geological and geophysical readings and samples. The apparatus comprises a cylindrical casing having ribs or grooves formed on its interior surface. A coupler is adapted to fit on the casing. Alignment means are formed on the casing and the coupler to co-operate to ensure alignment of the grooves in the casing with the grooves in an adjacent casing in the apparatus. Expandable bags may be attached to the exterior of the casing to help provide support and hydraulic seals between the casing and the surrounding materials.

Abstract: The isolating packer unit is made up of a cylindrical measuring casing one end of which is connected by a cylindrical coupler tube to an end of a similar measuring casing, this coupler tube having a measuring port normally closed by a valve which is operable from within the tube to open the port. An elongate elastic packer tube is mounted on and concentric with each casing and is secured at its ends to the casing. When the packer unit is in a well or bore hole, the packer tubes are expanded or inflated by fluid directed thereinto to engage the wall of the well or bore hole to isolate the measuring port of the coupler tube from the portions of the well or bore hole above and below the packer unit.