Abstract: A system for variably resisting flow of a fluid composition can include a flow passage and a set of one or more branch passages which intersect the flow passage, whereby a proportion of the fluid composition diverted from the passage to the set of branch passages varies based on at least one of a) viscosity of the fluid composition, and b) velocity of the fluid composition in the flow passage. Another variable flow resistance system can include a flow path selection device that selects which of multiple flow paths a majority of fluid flows through from the device, based on a ratio of desired fluid to undesired fluid in the fluid composition. Yet another variable flow resistance system can include a flow chamber, with a majority of the fluid composition entering the chamber in a direction which changes based on a ratio of desired fluid to undesired fluid in the fluid composition.

Abstract: A system configured to heat a portion of a formation includes a plurality of heat sources. At least one production well is in the formation. A bottom portion of the production well is a sump in an underburden of the formation below the heated portion of the formation. Fluids from the heated portion of the formation are allowed to flow into the sump. A pump system has an inlet in the sump. A production conduit is coupled to the pump system. The production conduit is configured to transport fluids in the sump out of the formation.

Abstract: A flow control screen (100) includes a base pipe (102) having a blank pipe section (104) and a perforated section (106). A filter medium (112) is positioned around a portion of the blank pipe section (104). A housing (114, 118, 120, 122, 124) is positioned around another portion of the blank pipe section (104) and the perforated section (106). A deformable element (150) is positioned between the housing and a portion of the perforated section including at least one production port (108) but not including at least one closure port (110) to define a production path (154) between the production port (108) and the filter medium (112) such that application of a sufficient pressure to the closure port (110) acts on the deformable element (150) to deform the deformable element (150) to substantially close the production path (154).

Abstract: A method and apparatus for a debris barrier assembly having a sleeve, an outer housing assembly coupled to the sleeve, and first and second biasing members disposed within the outer housing assembly. A support member is coupled to the sleeve and is in contact with an end of the first and second biasing members. The debris barrier assembly is coupled to a polished bore receptacle to prevent debris from entering the PBR. The debris barrier assembly is operable to compensate for a pressure differential between the internal region of the PBR and the external region of the surrounding wellbore. The debris barrier assembly and the PBR may be run in the wellbore on a work string, and the sleeve may be actuated to actuate a downhole tool connected to the sleeve to perform a downhole operation. The debris barrier assembly may be retrieved from the wellbore using the work string.

Abstract: A technique is provided to facilitate use of a service tool at a downhole location. The service tool has different operational configurations that can be selected and used without moving the service string.

Abstract: A downhole oilfield tool assembly is provided. The tool assembly comprises a mandrel, a valve oriented to block downwards flow through the mandrel in a closed position, a first piston located above the valve and at least partly around an outside of the mandrel. The first piston is configured to develop motive force from a pressure differential between an interior of the mandrel and an exterior of the downhole oilfield tool assembly.

Abstract: A dampered drop plug drops down a bore of a drill string. The dampered drop plug includes a retainer configured to land on an upward facing shoulder of a tubular sleeve, and a plug releasably coupled to the retainer. The plug couples to the retainer while at a first pressure in the bore and decouples from the retainer at a second pressure in the bore. The dampered drop plug lands on the upward facing shoulder of a tubular sleeve and actuates a first function. The plug then releases from the retainer, and passes fluid through the retainer at a controlled flowrate. The plug then lands on a ball seat and actuates a second function.

Abstract: A downhole circulating tool including a sleeve with a cam slot having continuous and symmetrical wishbone patterns through which a cam pin moves. The cam pin moves simultaneously through symmetrical portions of the cam slot to alternate the opening and closing of first and second fluid port openings. A first port opening is operable to communicate fluid to a drill bit when open. A second port opening is operable to communicate fluid directly into the borehole or casing wall of a wellbore when open.

Abstract: A downhole sleeve has a sliding sleeve movable in a bore of the sleeve's housing. The sliding sleeve is movable from a closed condition to an opened condition when a ball is dropped in the sleeve's bore and engages an indexing seat in the sliding sleeve. The sliding sleeve in the closed condition prevents communication between the bore and the port, and the sleeve in the opened condition permits communication between the bore and the port. In the closed condition, keys of the seat extend into the bore to engage the ball and to move the sliding sleeve open. In the opened condition, the keys of the seat retract from the bore so the ball can pass through the sleeve to another cluster sleeve or to another isolation sleeve of an assembly.

Abstract: A technique facilitates control over one or more well tools coupled to one or more corresponding control modules. Actuation of the control modules and the well tools may be achieved with three control lines connected to the one or more control modules. Transitioning of the control modules to sequential stages and the consequent actuation of the corresponding well tools is achieved by applying a single pressure level selectively through the three control lines.

Abstract: An interval can be divided into zones by inserting a series of plugs that register with specific profiles at predetermined intervals along a section of pipe. Each plug supports a releasable perforating gun that can release from the plug and perforate an interval for treatment such as fracturing or acidizing. A subsequent plug then isolates the just treated zone and the process is repeated working up toward the surface. When the full interval is treated the plugs can then be removed by making their cores disappear using a reaction or dissolving techniques. Mechanical alternative that push all the plugs to hole bottom or that retrieve them together or individually are possible alternative techniques for removal of the plugs from the treated interval before production is initiated.

Abstract: A conformable inflow control device includes a first tubular having a plurality of perforations therethrough, a second tubular positioned radially of the first tubular defining an annular space therebetween having at least one port therethrough, and a pressure drop device disposed at the annular space positioned between the plurality of perforations and the at least one port configured to create a drop in pressure in response to fluid flow therethrough. Also included is an expandable media disposed radially outwardly of the first tubular configured to expand while permitting fluid flow therethrough.

Abstract: The invention relates to an assembly to be run with a well tubular having openings provided in the wall and for being arranged in a well bore and thereby forming a space between said tubing and the well bore surface. The assembly comprising: first fluid control means and second fluid control means being provided in another opening in said well tubular. The assembly further having a set of packers for sealing of the space between said tubing and the well bore surface, said set of packers being positioned such that a part the tubular having both first and second fluid control means is located between the set of packers. The first fluid control means is adapted such that it is capable of blocking fluid flow from the interior of said well tubular to said space between said tubing and the well bore surface. The second fluid control means is adapted such that it is capable of blocking fluid flow.

Abstract: An apparatus for use in launching cement plugs in a well cementing operation, comprising: a cylinder (108); a piston (118) slideably received in the bore of the cylinder; and an actuator (120) extending from the piston through the cylinder and operable by the piston for launching a plug (114,116) from the apparatus into the well; wherein a resilient damper cartridge (124) is slideably mounted on the actuator in the cylinder so as to be contactable by the piston, and a series of frangible pins (122) is located in the cylinder wall so as to provide temporary limits to the movement of the cartridge in the cylinder as the piston slides along the cylinder.

Abstract: The invention provides a method comprising providing a composition comprising a pH trigger and a polymer able to be hydrated in a defined pH zone; injecting the composition with a pH outside the defined pH zone; triggering the pH trigger to adjust the pH of the composition within the defined pH zone; and allowing viscosity of the composition to increase and form a plug.

Abstract: A first method of controlling underwater oil well leaks is to place heavy metal javelins into the ruptured pipe. A second method is to fabricate or drop a series of self-stacking exterior collars around or over the ruptured pipe.

Abstract: A barrier valve system includes one or more barrier valves, a connection sub having a first portion and a second portion connecting one or more control lines to each other, and a replacement portion of the connection sub connectable to the first portion subsequent to retrieval of the second portion. The replacement portion has a port from an outside diameter of the replacement portion to an inside diameter of the replacement portion and seals disposed to define an annular space between the replacement portion and the first portion encompassing only valve opening ports in the first portion.

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

Abstract: Selective placement of conformance treatments in multi-zone well completions. A method includes injecting a relative permeability modifier into a zone and optimizing a ratio of desired fluid to undesired fluid produced from the zone, including adjusting at least one flow control device between fully open and fully closed configurations. Another method includes injecting a relative permeability modifier into multiple zones, one at a time, via respective flow control devices, and then producing fluid from each of the zones. Another method includes identifying which of the zones to treat by, for each of the zones: a) closing flow control devices corresponding to the other zones, and b) evaluating fluid produced from the zone; and injecting a conformance treatment into the zones identified as the zones to treat.

Abstract: An electronic actuation system for a pressure equalizing device in a downhole apparatus such as a wellbore plug is described. The system includes a pressure sensor for measuring pressure in the wellbore, and means for setting a reference pressure value using a measurement from the pressure sensor. In a method of use, an applied pressure value is determined using a measurement from the pressure sensor and the reference pressure value, and the device is actuated, or opened, when the applied pressure meets a pre-determined condition, such as falling within a pressure window for certain time period. The invention allows natural changes in wellbore pressure to be accounted for when detecting a pressure actuation event.

Abstract: A flapper in a subsurface safety valve has at least one magnet that comes in close proximity with another magnet mounted in a fixed position on the valve body. There is a fixed magnet on the body adjacent to the fully open and the fully closed positions of the flapper. In each case like poles on the flapper magnet and the housing magnet come in close proximity as the flapper reaches its fully open and fully closed positions. The orientation of like poles adjacent each other creates a repelling force that damps or eliminates shock loading.

Abstract: A flow restrictor for controlling the flow of cement or other fluid in oil wells comprises a plurality of restrictor elements, each defining first and second apertures, which are assembled in a stacked configuration and slidingly inserted into the well casing or other tubing so that the first apertures define a direct flowpath, preferably including a non-return valve, and the second apertures define a second, indirect flowpath between the elements and the inner surface of the tubing. The elements include seals for fluidly sealing each element in the bore of the tubing which are preferably slidably retractable and resiliently radially outwardly biased so as to adapt conformably to different tubing types having different internal diameters. The restrictor may slide along the tubing in use.

Abstract: An apparatus to protect the mounting area of casing and a locating profile and optionally a sliding sleeve valve and a flow path from the outside of the valve to the annulus when subsequent attachment of an expanded liner is intended and the expanded liner is to be cemented in place. A barrier sleeve, nose, and outer sleeve define a sealed cavity having a loose incompressible material inside that covers the mounting location on the casing. A locating profile and an optional sliding sleeve valve and a flow path from the outside of the valve to the annulus can be provided. The cementing of the casing takes place through the barrier sleeve. After the cementing, the sleeve and nose are drilled out and the incompressible material is removed to the surface with the drill cuttings. A liner is inserted in the casing and is preferably expanded into sealing contact.

Abstract: Gelled barrier fluids preventing the ingress of undesired fluids from subsurface environments into subsurface apparatus have a specific gravity which is within ±0.05 of the specific gravity of the undesired fluid.

Abstract: A bridge plug arrangement includes a plug having an upper end and a bottom end. The bridge plug arrangement also optionally includes a cylindrical seat. The bridge plug arrangement further includes a tubular member. The tubular member may be part of a casing string. The tubular member is configured to receive the plug and, when used, the seat. The plug and/or the seat may be fabricated from a frangible material. A method for diverting fluids in a wellbore using the bridge plug arrangement is also provided. The method may include landing the plug onto the seat within the wellbore below a subsurface zone of interest. Treatment fluids are then injected into the wellbore, where they are diverted through perforations and into a formation. The plug and/or seat is then optionally broken into a plurality of pieces through use of a downward mechanical force.

Abstract: One or more embodiments of a selectively openable and closable downhole tool. The wherein, the downhole tool can include an outer tubular member having an annulus port formed therethrough. The downhole tool can also include an inner tubular member. The inner tubular member can include an inner port. The inner port and annulus port can be selectively aligned to form a flow path therethrough by moving the inner tubular member relative to the outer tubular member. The downhole tool can also include a logic drum configured to selectively move the inner tubular member. The downhole tool can also include a piston assembly configured to move the logic drum.

Abstract: A downhole assembly includes an apparatus for generating a fluid pressure pulse downhole. A disclosed apparatus for generating a fluid pressure pulse downhole includes an elongate, generally tubular housing defining an internal fluid flow passage and having a housing wall. The apparatus also includes a device for selectively generating a fluid pressure pulse, the device having a cartridge which can be releasably mounted entirely within a space provided in the wall of the tubular housing. The internal fluid flow passage defined by the tubular housing is a primary fluid flow passage. A secondary fluid flow passage has an inlet which communicates with the primary fluid flow passage. The cartridge houses a valve actuable to control fluid flow through the secondary fluid flow passage to selectively generate a fluid pressure pulse. Data relating to a measured downhole parameter or parameters can be transmitted to surface via the pressure pulses.

Abstract: Methods and apparatus are provided for oil and gas well completions without conventional perforations or jet cutting. One or more frac gate tool(s) are included in the production casing string or liner which is cemented in the hole. The frac gates have a sleeve that is openable by a shifting tool to allow fluids inside the casing or liner to exit through ports and breakdown and treat the adjacent formation. Casing flapper valves are placeable above a lower frac gate to isolate the treated formation from a higher producing zone during treatment of the higher zone through a higher frac gate. A single hydraulically actuated shifting tool is usable to open the frac gates and close the casing flapper valves.

Abstract: An apparatus for fluid treatment of a borehole includes: a tubing string having a long axis and an upper end, a first, second and third ports opened through the wall of the tubing string; packers operable to seal about the tubing string and mounted on the tubing string; a closure on each port and each being actuable between a closed port position and a position permitting fluid flow through the ports from the tubing string inner bore; and a closure actuating mechanism for actuating the first closure and the second closure together from their closed port positions to their positions permitting fluid flow, while the third closure remains in the closed port position.

Abstract: One apparatus for releasing a chemical in a well bore includes a casing collar configured to couple to a casing string. A chemical container is disposed within the casing collar, and the casing collar is configured to release the chemical from the chemical reservoir.

Abstract: An apparatus for indicating the orientation of a structure which includes an orienting sub releasably connected at an outer case. The orienting sub is at a preselected orientation relative to the structure. A change in fluid pressure of a predetermined magnitude of flow rate through the orienting sub will indicate that the structure is at a desired orientation in the well.

Abstract: A chemical injection system for controlling injection of an injection fluid from an injection fluid supply at a surface location into a production tubing assembly having an upper flow path, a first flow zone, and a second flow zone. The chemical injection system comprises a first fluid injection line configured to inject the injection fluid into the first flow zone and a second fluid injection line configured to inject the injection fluid into the second flow zone. A main fluid supply line is configured to fluidly connect both the first fluid injection line and the second fluid injection line to the injection fluid supply.

Abstract: A method of actuating a well tool includes the steps of: increasing pressure in a fluid line of a fluid metering device; closing a pilot-operated valve in response to the pressure increasing step; and discharging a predetermined volume of fluid from the metering device in response to the pressure increasing and valve closing steps. A fluid metering device for a well tool includes a piston separating chambers; and a pilot-operated valve which selectively prevents fluid communication between the chambers in response to at least a predetermined pressure being applied to a fluid line of the metering device, and which permits fluid communication through the valve between the chambers in response to pressure in the fluid line being less than the predetermined pressure. A greater pressure may be applied to the fluid line to thereby bypass the metering device and allow fluid to discharge from the line.

Abstract: A double swivel for use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through double sleeves which are sealably and rotatably supported thereon for relative rotation between the sleeves and mandrel. The mandrel and sleeves have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit.

Abstract: A method of delivering material, typically lost circulation material (LCM), into a hole via a tubular string comprises: opening a bypass port in a tubular string located in a drilled hole, the bypass port being provided above fluid outlets in the distal end of the string; delivering material through the string from surface, the material passing through the bypass port and into the drilled hole; and locking a volume of fluid in the string between the bypass port and the fluid outlets such that fluid is prevented from passing from the hole into the string via the fluid outlets.

Abstract: A multiple-positioning mechanical shifting system including for used in hydrocarbon wells. The system includes a shifting tool capable of selectively positioning a mechanical sliding sleeve valve in multiple operational positions that varying the flow rate and/or volume of tubing string fluid flowing to the well annulus. The system also includes a multiple position mechanical choke valve. A method of operating the mechanical choke valve using the shifting tool is described.

Abstract: A downhole isolation tool including a sub, a sleeve disposed in the sub, and a ball seat mandrel coupled to the sleeve, the ball seat mandrel having at least two ball seats axially aligned with at least two throughbores disposed within the ball seat mandrel. A method of isolating a well, the method including running a downhole isolation system into a well, wherein the downhole isolation system includes a first downhole isolation tool, the first downhole isolation tool including a first sub, a first sleeve disposed in the sub, and a first ball seat mandrel coupled to the first sleeve, the first ball seat mandrel having at least two ball seats of a first size axially aligned with at least two throughbores disposed within the first ball seat mandrel, dropping at least two balls of a first size into the well, and seating the at least two balls of the first size in the at least two ball seats of the first ball seat mandrel.

Abstract: A well tool for use with a subterranean well can include an elongated passageway and a plug which prevents fluid communication through the passageway for a predetermined period of time. The plug can including an anhydrous boron compound, whereby the predetermined period of time is determined by a length of the anhydrous boron compound. A method of operating a well tool in conjunction with a subterranean well can include exposing an anhydrous boron compound to an aqueous fluid, with the anhydrous boron compound being included in a plug which prevents fluid communication through a passageway of the well tool. The well tool can be operated in response to fluid communication being permitted through the passageway a predetermined period of time after the exposing step.

Abstract: For wellbore fluid treatment, sliding sleeves deploy on tubing in a wellbore annulus. Operators deploy a plug down the tubing to a first sleeve. The plug seats in this first sleeve, and pumped fluid pressure opens the first sleeve and communicates from the tubing to the wellbore annulus. In the annulus, the fluid pressure creates a pressure differential between the wellbore annulus pressure and a pressure chamber on second sleeves on the tubing. The resulting pressure differential opens the second sleeves so that fluid pressure from the tubing can communicate through the second open sleeves. Using this arrangement, one sleeve can be opened in a cluster of sleeves without opening all of them at the same time. The deployed plug is only required to open the fluid pressure to the annulus by opening the first sleeve. The pressure chambers actuate the second sleeves to open up the tubing to the annulus.

Abstract: A downhole valve assembly is attached to a drillstring and includes an upper drillstring connection, a lower drillstring connection, and a tubular body comprising a through bore, and further includes a weight activated mechanism configured to close the through bore when the drillstring is lifted.

Abstract: A technique is provided to facilitate fluid flow and pressure control in a well with an interventionless flow valve system. The valve system is coupled to a well component string deployed downhole in a wellbore. The valve system controls flow and pressure between an interior and exterior of the string and comprises a valve controlled by an activation device. The activation device is responsive to a unique pressure and time signal transmitted downhole.

Abstract: A hydraulic coupler for providing fluid communication between adjacent members that includes a two way check valve formed from a double headed poppet set in a hollow cylinder with corrugated bellows like walls. Contoured bores are provided in the cylinder ends and the poppet heads are profiled to match the contour of the bores. When the heads are seated in the bores they form a sealing surface to block fluid from flowing through the coupler. Compressively preloading the cylinder before assembly provides a sealing force between the heads and the bores. Axially compressing the cylinder with respect to the poppet unseats the heads from the bores to form a flow path through the coupler.

Abstract: An apparatus for regulating fluid-flow during a primary cementing job comprises a bottom cementing plug, adapted to house a one-way valve and means to regulate fluid flow through the plug interior. The apparatus is useful for minimizing or preventing free fall or U-tubing during primary cementing. The apparatus is compatible with conventional cementing-plug launching systems.

Abstract: Equipment for servicing subterranean wells are disclosed. Particularly, a cementing plug that is equipped to activate autofill float equipment, and a method by which the plug is employed to activate autofill equipment. The bottom cementing plug contains an activation device that is released when the plug lands on the autofill equipment, then enters the autofill equipment, triggering the activation of check valves. The activation device may also contain a chemical substance that is released into the well when the activation device exits the bottom cementing plug.

Abstract: A fracturing operation is done in open hole. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. In formations that need annular space isolation, the string in a preferred embodiment can have an external material that grows to seal the annular space in lieu of a traditional cementing operation.

Abstract: An apparatus and method is provided for controlling and/or halting the uncontrolled flow of petroleum and/or natural gas from an open well head on the sea floor in which the well head is in communication with a subterranean formation. The method includes lowering a fluid control device from a drilling ship to an alignment means positioned above an open well casing through which the petroleum and/or natural gas is flowing in an uncontrolled manner, then lowering the fluid control device through and/or adjacent to the alignment means and into the open well casing until a lower section of a fluid control device enters the open well casing. The fluid control device includes an elongated member at its tip, having a diameter smaller than the inside diameter of the well head casing.

Abstract: Systems and methods for sealing a wellbore are provided. The wellbore has a pipe therein for the passage of fluid therethrough. The system is provided with a BOP positionable about the pipe and at least one seal assembly positionable about the BOP. Each of the seal assemblies has a plurality of blocks positionable within the BOP, at least one actuator for selectively moving the blocks to a contact position surrounding the pipe, and a plurality of pipe seals carried by the blocks for creating a seal about the pipe of the wellbore. Each block has an opening extending into a cavity therein. Each pipe seal is positionable in one of the cavities and flowable through the opening thereof as the blocks are moved into the contact position whereby at least a portion of a pressure applied to the pipe seals is released from the blocks.

Abstract: Systems and methods for sealing a wellbore are provided. The system is for sealing a wellbore having a pipe therein for the passage of fluid therethrough. The system is provided with a BOP positionable about the pipe and at least one seal assembly positionable about the BOP. Each of the seal assemblies comprises a plurality of blocks positionable within the BOP, at least one actuator for selectively moving the blocks to a contact position surrounding the pipe and a plurality of pipe seals for creating a seal about the pipe. The seals are carried by the plurality of blocks. At least one of the pipe seals in each block is selectively extendable therefrom for sealing engagement about the pipe after the blocks are moved to the contact position whereby the pipe seals are prevented from extending between the blocks as the blocks are moved to the contact position.

Abstract: A drilling operation suspension spool system which operates to provide a dual sealing barrier for a well during suspension of drilling operations. The system includes a spool having a spool adapted to be secured in fixed relation to a wellhead and a dummy hanger adapted to be matedly inserted into the spool. The dummy hanger includes an annular sleeve and a removable axial plug disposed within the annular sleeve insert. A plurality of extendable and retractable locking pins secure the dummy hanger in place.

Abstract: Methods and apparatus for use with gas-filled downhole tools are disclosed herein. A disclosed example method includes opening an isolation valve of a downhole tool, wherein the isolation valve is in fluid communication with first and second ports of the downhole tool, and wherein the first and second ports are in fluid communication with respective first and second ends of an interior cavity of the downhole tool; coupling a source of inert gas to the first port and flowing the inert gas into the interior cavity of the downhole tool to expel air from the interior cavity through the second port; closing the second port when the air is expelled from the interior cavity; and closing the isolation valve to seal the inert gas in the interior cavity.