Abstract: An additional string is run through an existing string using a running string. With the strings overlapping an upper inflatable secures them together leaving gaps. The upper inflatable creates an upper expanded zone where the swage assembly is then built. The swage assembly has a seal and upon pressure being applied between the upper inflatable and the seal the swage assembly releases the running string and is pushed to expand the additional string until tagging a cement shoe. The running string is rejoined to the swage assembly and after cementing a lower inflatable is deployed to make a bell and to set an external packer if used. If there is an external packer the shoe releases and on the way out of the hole the upper inflatable sets a seal in the lap.

Abstract: An improved rotating head having superior sealing, performance and versatility.

Abstract: A tool comprising a fluid path defined by a bore formed within a tubular body includes a guided sleeve and a reciprocating sleeve disposed within the bore. A gearwheel is located on an outer surface of the guided sleeve and at least one pawl located on an inner surface of the reciprocating sleeve. When the reciprocating sleeve translates axially, it rotates in a first direction. As the reciprocating sleeve rotates, the at least one pawl pushes the gearwheel and causes the guided sleeve to rotate in the first direction into a new position.

Abstract: A high pressure seal adapter for a conductor housing of a wellhead, the high pressure seal adapter having a unitary body comprising: a first circular bore extending through said unitary body; and a second circular bore adjacent said first circular bore and extending through said unitary body; wherein said seal adapter is capable of being installed in said conductor housing. The high pressure seal adapter may further include at least one seal extending around a perimeter of said unitary body, said at least one seal contacting said conductor housing. The adapter may receive a high pressure riser in said first circular bore when said seal adapter is installed in said conductor housing, said high pressure riser having a lower surface that contacts said flange and at least one seal extending around an outside perimeter of said riser.

Abstract: A well system comprising, in combination, a recipient ground area, a surface casing, a source well casing, a return well casing, and a return pipe. The return pipe is located within the return well casing, and the return well casing is located within the source well casing. This arrangement allows the removal of water from, and the return of water to different strata through the same drilled well hole, while also monitoring different aquifers water quality and/or aquifer parameters.

Abstract: Downhole tools, such as MWD modules (or components), may be coupled together with a coupler (or coupling device) having a shaft housing with slidable electrical connectors disposed at each end. The electrical connectors may each be supported in connector housings disposed with springs or other movable devices. In a first position, the electrical connectors may extend past the ends of the shaft housing. The slidable connector housings allow the electrical connections to be made before the sleeves connecting (or mechanically connecting) the MWD modules with the coupler are begun to be threadedly attached with the coupler. Each of the connector housings may have a key configuration on their exposed end. The shaft housing may also have key configurations on its ends. The key configurations of the connector housings and the shaft housing may be configured to mate with compatible ends of MWD modules.

Abstract: A system in some embodiments includes a system, having a seal assembly, including an inner energizing ring, an outer energizing ring, a load ring disposed between the inner energizing ring and the outer energizing ring, a sealing element, and a lock ring. Further other embodiments provide a method of sealing, including rotating an inner energizing ring in a direction to move the inner energizing ring in a first axial direction to seat a seal, rotating an outer energizing ring in the direction to wedgingly engage and set a lock ring in a radial direction, and rotating a load ring in the direction to move the load ring in a second axial direction to set the lock ring.

Abstract: An assembly is provided to attach a whipstock to a mill/drill bit. The assembly includes an upper collar adapted for installation around a shank of the mill/drill bit. At least one connecting member is mounted at a first end to the upper collar. The connecting member extends downwardly from the upper collar and is adapted to fit within a junkslot of the mill/drill bit to which the upper collar is attached. A whipstock attachment structure is mounted to a second end of the at least one connecting member.

Abstract: An offshore drilling riser joint has a central riser pipe, a number of auxiliary lines mounted around it, and a buoyancy module assembly of a buoyant material. A pair of upper thrust sleeves slide over two of the auxiliary lines, each of the upper thrust sleeves having a flange in contact with an upper end of the buoyancy module assembly. Each of the upper thrust sleeves transfer upward thrust imposed by the buoyancy module assembly to an upper support flange mounted to the central riser pipe. A pair of lower thrust sleeves slide over two of the auxiliary lines. Each lower thrust sleeve has a lower thrust flange that is engaged by a lower end of the buoyancy module assembly. Each of the lower thrust sleeves transfer weight of the buoyancy module assembly while out of water to a lower support flange mounted to the central riser pipe.

Abstract: A coupling device includes an upper adapter and a lower adapter. The lower adapter may be pre-installed on a downhole tool and positioned in a wellbore. The upper adapter may be attached to a conveyance and lowered into the wellbore for connection with the lower adapter. The upper adapter may be coupled to the lower adapter by sliding over the lower adapter and applying weight to actuate a locking mechanism. After coupling, axial and torque load may be transmitted from the conveyance to the downhole tool.

Abstract: The disclosure includes a system, method, and tool for logging while pulling. The disclosed system includes a tool and a bottom hole assembly, and the tool engages with the bottom hole assembly. The tool includes an elongated body, a retarder positioned on the elongated body, and a locking ring positioned on the elongated body. The retarder has at least one point of contact with an interior surface of a drill pipe. The disclosed method includes assembling the tool, providing a landing ring on a bottom hole assembly, free dropping the tool to the bottom hole assembly, and engaging the landing ring of the bottom hole assembly with the locking ring of the tool so that a portion of the tool extends below the bottom hole assembly.

Abstract: A box and pin coupling for a drilling riser having an actuator assembly with an attached dog. The actuator assembly includes an actuation rod having an end affixed to the dog. A portion of the rod is circumscribed by an annular sleeve, where the outer surface of the sleeve is threadingly attached to one of the box or pin. A shoulder is formed on the rod outer circumference between the sleeve and the end of the rod attached to the dog. A retainer cap is provided on the end of the rod opposite where it attaches to the dog. The sleeve abuts the rod on one end, and the retainer cap on the other, so that rotating the sleeve axially moves the actuation rod, that in turn moves the attached dog into or out of engagement with a profile on the other of the box or pin.

Abstract: A hydraulic connector to provide a fluidic connection between a fluid supply and a downhole tubular, the connector comprising: a body; an engagement assembly comprising an extendable portion selectively extendable from the body, the engagement assembly being configured to extend and retract a seal assembly disposed at a distal end of the extendable portion into and from a proximal end of the downhole tubular; and a valve assembly operable between an open position and a closed position, the valve assembly being configured to: allow a fluid to communicate between the fluid supply and the downhole tubular through the seal assembly when in the open position; and prevent fluid communication between the fluid supply and the downhole tubular when in the closed position.

Abstract: Disclosed is a downhole well filter (800) and method of use in a tubing string with a power head (704) for creating reverse flow. The filter assembly includes an inner pipe (820) into which fluid flow is directed. The inner pipe is positioned within a cylindrical screen member (830). The well fluid flows through the screen member and debris from the fluid is deposited in the annulus (832) between the inner pipe and screen member. The screen member has a cap (860) at its upper end to prevent fluid from escaping from the upper end of the screen member. The cap may have a pop off valve (870) so fluid can escape from the screen member when the screen becomes clogged with debris or pressure builds within the screen member.

Abstract: Contemplated hybrid riser towers are configured such that individual riser lines can be added or removed via submarine ROV. Most preferably, riser lines are made from a housing and syntactic foam that encloses a riser pipe to so provide insulation and buoyancy. In further preferred aspects, hybrid riser towers are coupled to each other via a truss to allow expansion via SCR and/or to provide a riser porch.

Abstract: A top drive-pumpable cement head is provided for cementing a casing into a wellbore comprising a top sub portion with a top drive connection connectable to a top drive shaft to receive cement and impart translational and rotational forces to the casing simultaneously during cementing, and a ball launching assembly for housing and launching one or more launching balls. A bottom sub portion comprises a casing sleeve for housing one or more hollow wiper plugs and a tattle tale wire. The cement head also comprises a hammer union. The ball launching assembly is pre-loadable with the launching balls, the bottom sub is pre-loadable with the one or more hollow wiper plugs and a tattle tale wire and the top sub and the bottom sub are connectable via the hammer union for storage, prior to cementing operations. A method is also provided for assembling a cement head for completing a casing in a wellbore.

Abstract: A technique facilitates actuation of a downhole tool in a well string. The downhole tool may be actuated hydraulically via the controlled flow of a hydraulic fluid under pressure to the downhole tool through a port. Flow of the pressurized fluid through the port is controlled by a barrier member which may be opened by a plunger working in cooperation with the barrier member. Movement of the plunger is controlled by selectively increasing the pressure acting on the plunger through, for example, actuation of an expansion device or other suitable device.

Abstract: An apparatus comprises a support member operable to be disposed within a tubular member that includes a threaded connection with a pin member. The tubular member is coupled to an expansion device that is operable to radially expand the tubular member and a pin catcher that is operable to engage the pin member as the expansion device and pin catcher move axially through the tubular member.

Abstract: A borehole metal member bonding system includes, a first metal member, a second metal member proximate the first metal member, and a pyrotechnic composition positioned proximate the first metal member and the second metal member configured to bond the first metal member to the second metal member subsequent undergoing an exothermic reaction while within a borehole.

Abstract: A system can include multiple explosive assemblies, each assembly comprising an outer housing, an explosive component rotatable relative to the housing, and a selective firing module which causes detonation of the component in response to a predetermined signal. A method can include assembling multiple explosive assemblies at a location remote from a well, installing a selective firing module, an electrical detonator and an explosive component in a connector, and connecting the connector to an outer housing, and then transporting the assemblies from the remote location to the well. A well perforating method can include assembling multiple perforating guns, each gun comprising a gun body, a perforating charge, and a selective firing module which causes detonation of the charge in response to a predetermined signal. The guns are installed in a wellbore, with the charge of each gun rotating relative to the respective gun body.

Abstract: A method can include interconnecting a well tool in a well tool assembly with a shock mitigating connection, the interconnecting being performed without threading, and positioning the well tool assembly in a wellbore. A well perforating assembly can include at least two perforating devices, a detonation train extending through the perforating devices, and a shock absorber positioned between the perforating devices. A method of assembling a perforating assembly can include, prior to installing the perforating assembly in a wellbore, pushing one perforating device connector into another perforating device connector without threading the connectors together, thereby: a) preventing disconnection of the connectors and b) making a connection in a detonation train. A well system can include a perforating assembly including multiple perforating guns and multiple shock absorbers. Each shock absorber may be interconnected between at least two of the perforating guns.

Abstract: A method can include interconnecting a well tool in a well tool assembly with a shock mitigating connection, the interconnecting being performed without threading, and positioning the well tool assembly in a wellbore. A well perforating assembly can include at least two perforating devices, a detonation train extending through the perforating devices, and a shock absorber positioned between the perforating devices. A method of assembling a perforating assembly can include, prior to installing the perforating assembly in a wellbore, pushing one perforating device connector into another perforating device connector without threading the connectors together, thereby: a) preventing disconnection of the connectors and b) making a connection in a detonation train. A well system can include a perforating assembly including multiple perforating guns and multiple shock absorbers. Each shock absorber may be interconnected between at least two of the perforating guns.

Abstract: A rotating flow head has a lubricated bearing pack for isolating bearing elements from wellbore fluids under pressure. The bearing pack, having a rotating cylindrical sleeve, bearing elements and two seal assemblies, is secured within an assembly bore of a stationary housing by a retainer plate accepting a plurality of lag bolts circumferentially spaced around a top portion of the stationary housing. Each of the seal assemblies have at least one sealing element having a body, an annular cavity, an inner sealing surface, and a flange that distends radially outwardly when axially compressed. A loading ring fit to the annular cavity urges the inner sealing surface radially inwardly to sealingly engage the rotating cylindrical sleeve. The inner sealing surface further comprises a first and second sealing surface and a debris channel therebetween.

Abstract: A fiber optic coiled tubing assembly of multiple segments and coupling mechanism therefor. The assembly may be assembled from multiple coiled tubing segments which are pre-loaded with fiber optic line. Thus, the coupling mechanism may be employed for physical coupling of the coiled tubing segments as well as communicative coupling of the lines of the separate segments to one another. As such, pumping of a single fiber optic line through the coiled tubing assembly following coupling of the segments may be avoided. This may be of particular benefit for offshore operations where the joining of multiple coiled tubing segments is likely due to crane load capacity limitations and where such pumping may consume vast amounts of time.

Abstract: A subsea wellhead assembly provided over a wellbore, the assembly having a wellhead housing, a tubing hanger in the housing, a production tree on the wellhead housing above the tubing hanger, and a control circuit that passes axially downward from the production tree and through the tubing hanger. A tree stab assembly may be included that is set between the tubing hanger and production tree. The wellhead assembly can also include a casing hanger landed in the housing, casing attached to the casing hanger, and tubing attached to the tubing hanger.

Abstract: A jumper including an upstream connector configured to communicate with an umbilical, and a downstream connector configured to communicate with an end device. The jumper also includes a conduit having a first end attached to the upstream connector and a second end attached to the downstream connector, a plurality of valves, and a programmable processor.

Abstract: A subsea wellhead assembly includes an outer wellhead member with a bore containing at least one conical generally upward facing load shoulder that inclines relative to an axis of the bore. The outer wellhead member also contains an overpull recess having a generally downward facing overpull shoulder positioned below the at least one generally upward facing load shoulder. An inner wellhead member is lowered into the housing, the inner wellhead member having at least one conical downward facing load shoulder that inclines relative to an axis of the bore. A load ring has an inner profile that slidingly engages the downward facing load shoulder and an outer profile that slidingly engages the upward facing load shoulder.

Abstract: A control line positioning apparatus (10) comprising a retainer arm (30), having a control line retainer thereon, is driven between a removed position with the retainer arm (30) positioned adjacent to a base and adjacent to a rig floor and a raised position with the retainer arm (30) raised by a drive member to a raised position to hold one or more control lines (90) along a portion of the length of a pipe string (80) to facilitate application of a clamp to secure the control lines to the pipe string (80). In one embodiment, the retainer arm (30) may be releasably secured to a docking assembly (50) disposed adjacent to the pipe engaging apparatus and adjacent to a rig floor. In one embodiment, the control line positioning apparatus may comprise an ascending control line pathway (112) comprising a plurality of rolling members to direct one or more control lines to a retainer assembly.

Abstract: Apparatuses and methods for controlling the connection speed of downhole connectors in a subterranean well are disclosed. An apparatus includes a first assembly having a first downhole connector and a first communication medium that is positionable in the well. A second assembly includes a second downhole connector and a second communication medium and has an outer portion and an inner portion that are selectively axially shiftable relative to one another. A lock assembly including at least one lug initially couples the outer and inner portions of the second assembly together such that, upon engagement of the first assembly with the second assembly downhole, the lug is radially shifted releasing the lock assembly to allow axial shifting of the outer portion of the second assembly relative to the inner portion of the second assembly, thereby operatively connecting the first and second downhole connectors to enable communication between the communication media.

Abstract: A method of producing a filtration system for filtering a chemical fluid used in a hydrocarbon extraction well is provided. The method comprises providing a filter arrangement comprising an inlet end and an outlet end, connecting the inlet end to a first fluid flow passageway using a first hydraulically operated connector, and connecting the outlet end to a second fluid flow passageway using a second hydraulically operated connector.

Abstract: Methods and apparatus for use in a well. A first component made of a first material and a second component made of a second material are provided. The first and second materials are dissimilar to each other. An adaptor is also provided, where part of the adaptor is made of or compatible with the first material, and another part of the adaptor is made of or compatible with the second material. The first component is connected to the adaptor, as is the second component. The combined adaptor and first and second components are deployed into a downhole well system.

Abstract: A downhole tool for positioning in a wellbore comprises a tool main body, an electric motor disposed within the tool main body, the motor comprising a rotor rotatably attached to a stator, and a linear actuator assembly disposed within the motor for transforming a rotary output of the motor into a linear displacement.

Abstract: A technique enables efficient deployment of instrumentation gauges in a wellbore. The technique comprises preparing offline a plurality of assemblies having a combined packer and gauge mandrel with an associated gauge. Each assembly is combined with a segment or length of instrumentation cable that is fully spliced with the gauge during offline assembly time. Various splice halves also can be assembled during offline assembly time.

Abstract: An example method comprises securing a sleeve around at least a portion of a downhole tool, deploying the sleeve and the downhole tool into a wellbore penetrating a subterranean formation, and retrieving the sleeve and the downhole tool from the wellbore. The step of securing the sleeve around the at least portion of the downhole tool may be performed at the well site.

Abstract: A method for installing a horizontal or inclined subsurface heater includes placing a heating section of a heater in a horizontal or inclined section of a wellbore with an installation tool. The tool is uncoupled from the heating section. A lead in section is mechanically and electrically coupled to the heating section of the heater. The lead-in section is located in an angled or vertical section of the wellbore.

Abstract: A hanger system is provided for supporting a cable-supported dewatering pump in a gas well. A dewatering pump is supported in a downhole location by a cable. A cable hanger bears the weight of the cable and the weight of the dewatering pump. A pulling tool is configured to detachably connect to the cable hanger and to support the weight of the cable hanger, cable and gas well dewatering system as it is pulled out of a seated position in the well.

Abstract: An actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached externally to the housing assembly and interconnected to the line. A method of constructing an actuator control system includes the steps of: assembling a modular controller, the modular controller including a control valve therein for controlling operation of an actuator via a hydraulic line; testing the modular controller, including functionally testing the control valve; and then attaching the modular controller to a housing assembly having the line formed therein. Another actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached separately to the housing assembly and interconnected to the line via a manifold of the modular controller, the manifold including a concave interface surface which receives the housing assembly therein.

Abstract: A connector guard is provided to protect one or both downhole connectors during wellbore run in prior to mating downhole. The connector guard may comprise dissolvable or degradable material and include an engagement sections and a removal feature. The connector guard may be dissolved or degraded via a reactive agent or temperature either introduced downhole proximate to the guards or contained within a chamber included in or created by a connector guard. The connector guard may be further coupled by a non-reactive cover in order to control the rate of reaction of the dissolvable material. The cover may be breached prior to mating of the downhole connectors.

Abstract: Systems for coupling ends of elongated heaters and methods of using such systems to treat a subsurface formation are described herein. A system may include two elongated heaters with an end portion of one heater abutted or near to an end portion of the other heater and a core coupling material. The core coupling material may extend between the two elongated heaters. The elongated heaters may include cores and at least one conductor substantially concentrically surrounds the cores. The cores may have a lower melting point than the conductors. At least one end portion of the conductor may have a beveled edge. The gap formed by the beveled edge may be filled with a coupling material for coupling the one or more conductors. One end portion of at least one core may have a recessed opening and the core coupling material may be partially inside the recessed opening.

Abstract: A methodology reduces the needed number of personnel on a rig by enabling performance of a variety of functions from a remote location. The method comprises utilizing a plurality of observation devices which monitor rig parameters remotely. Data from the observation devices is transmitted to a remote operations center used to analyze the data for determining operational changes to the rig. Control instructions may then be transmitted to the rig to implement the operational changes.

Abstract: An expansion device for a wellbore servicing tool, comprising a wedge comprising a frusto-conical wall having a tip end, the wedge being configured coaxially along a central axis, a plurality of slip segments, each slip segment comprising an inner surface having an incline surface, and at least one bridge joining each of the incline surfaces to the frusto conical wall. A method of operating a wellbore servicing tool, comprising longitudinally compressing an expansion device along a central axis, upon sufficient compression, separating plural slip segments from a wedge, moving the wedge relative to the slip segments, upon sufficient movement of the wedge relative to the slip segments, separating at least two slip segments from each other.

Abstract: A continuous feed injection unit used for example for injection and removal of continuous well string from wells operates in a dual speed configuration. The unit comprises a first hydraulic motor, a second hydraulic motor, cooperating continuous well string gripping chains connected to be driven by the first and second hydraulic motors, a hydraulic power supply connected to provide pressurized fluid to the first and second hydraulic motors and a control system for the hydraulic power supply. The control system for the hydraulic power supply has a motor speed control valve with at least a first and second operating configuration, the first operating configuration providing power fluid to the first and second hydraulic motors in parallel and the second operating configuration providing power fluid to the first and second hydraulic motors in series. The hydraulic power supply may be a conventional power tong hydraulic supply.

Abstract: A communication arrangement is disclosed for communication between a downhole line and a wellhead body having a through-hole and a valve member for closing the through-hole. The communication arrangement provides a fluid passage that extends from a wellhead body port to the downhole line thus allowing communication between the wellhead body and a safety valve or valves and/or the injection of chemicals or fluids into the well without the need to rework the valve member or disable the valve member.

Abstract: In a downhole rod-driven pump, continuous rod is used to drive the pump. The continuous rod is connected directly to the drive eliminating the need for a polish rod and an uphole coupling. A coupling is used to connect the continuous rod to the pump reducing restrictions in the production annulus and wear on the production tubing. Further, clean out tubing can be inserted into the production tubing beside the continuous rod and can extend therein to the pump without restriction. When the coupling is a threaded coupling, the continuous rod can be rotated in an appropriate direction to release the continuous rod from the pump when the pump is stuck. When the coupling is a shear coupling, the shear coupling can be sheared for releasing the pump from the continuous rod. When the pump is a progressing cavity pump and the coupling is a shear coupling, the continuous rod can be reverse rotated for changing the direction of pumping and if the rotor thereafter remains stuck, the shear coupling can be sheared.

Abstract: The invention relates to a riser pipe section comprising a main tube (2), at least one auxiliary line element (3) arranged substantially parallel to said tube (2), characterized in that the ends of main tube (2) comprise connecting means (8) allowing longitudinal stresses to be transmitted and in that the ends of auxiliary line element (3) comprise linking means (5-6) allowing longitudinal stresses to be transmitted.

Abstract: A technique facilitates use and installation of a large bore completion system. The technique comprises providing infrastructure during an initial completion stage and deploying a monitoring system. Based on data from the monitoring system, an intelligent completion may later be deployed as necessary to control production, injection, or other well related fluid flows.

Abstract: A subsea well assembly has a tubing hanger that lands and seals in a wellhead housing. A tree block is lowered through the drilling riser into engagement with the tubing hanger. The tree block has a lower portion that inserts and latches into the bore of the wellhead housing. The drilling riser is disconnected, and a module is lowered onto the tree block, the module having a choke and controls for controlling the well. The master valve for production is the downhole safety valve in the tubing. The wing production valve is a ball valve located in the flow passage of the tree block.

Abstract: A percussion drilling assembly for boring into the earth. In an embodiment, the assembly comprises a tubular case having a central axis and a lower end. In addition, the assembly comprises a driver sub having an upper end threadingly engaged with the lower end of the case. Further, the assembly comprises a annular locking member disposed about the driver sub. The annular locking member engages the case and the driver sub and restricts the rotation of the driver sub relative to the case about the central axis.

Abstract: An integrated apparatus for use in hydrocarbon-producing wells is provided. A device for controlling inflow from a subterranean formation (ICD), a filtration medium for fine particle exclusion and a sealing element (packer) are disposed along a single cylindrical mandrel, preferably an oilfield tubular. The apparatus may be used in a completion method to enhance production rates and increase the total recovery from a subterranean hydrocarbon-producing formation.

Abstract: A wet connection system suitable for use in hydrocarbon wells preferably comprises one or more elongate, small diameter conduits (50) which extend down the wellbore (2) and terminate adjacent a locating structure (11) on the production tubing (10). Equipment (70) deployed at the locating structure is connected to one or more self supporting conductors (30) which extend down the conduits from the wellhead (5). Preferably the conductors are retractable and the conduits are sealingly connected to the equipment, allowing the equipment and conductors to be deployed and recovered independently of each other and to be flushed with dielectric oil (99) pumped down the conduits after re-connection.