Abstract: A tool is provided for installing a mandrel in a wellhead assembly. The tool includes an assembly having multiple independently translatable and rotatable members. The tool includes an inner member disposed in an inner sleeve. The inner member may be disposed in a first position and second position, such that in the first position the inner sleeve freely rotates and in the second position rotation of the inner sleeve causes rotation of the inner member. An outer sleeve is disposed over the inner sleeve and may be coupled to a hold down ring. The inner member may be coupled to mandrel. The tool may be inserted into a wellhead assembly and the outer rotated to engage the hold down ring, the inner and outer sleeve may be translated axially to allow rotation of the inner member to disengage the tool from the mandrel.

Abstract: The cable handling apparatus includes a trolley beam, where the trolley beam is adapted to allow a cable trolley to slide thereon and an articulating arm. The articulating arm is hingedly coupled to the trolley beam, and the articulating arm is hingedly coupled to a piece of wellsite equipment. The articulating arm is repositionable between a retracted position and an extended position.

Abstract: The invention concerns a method for installing an apparatus for monitoring physical parameters in an annulus of an oil and/or gas well having a well head. The apparatus comprises a sensor plug including a sensor and a flange assembly arranged with a bore holding a signal processing unit for communication with the sensor. The method comprises the following steps; installing the sensor plug including the sensor in a passage in the well head, which passage communicates with an annulus of the well, connecting a cable connector to the sensor plug, which cable connector is attached to an end of a cable, connecting the sensor of the sensor plug to the signal processing unit in the bore of the flange assembly, positioning the bore of the flange assembly essentially coinciding with the passage of the well head thereby inserting the cable connector into the bore and attaching the flange assembly to the well head thereby.

Abstract: A blowout preventer and flow regulator, comprising blocks, each having a channel and plates to close it. The blocks are placed over a pipe through which oil or other fluid is escaping, so that the pipe is in their channels. Alongside the channel in each block are one or more plates, having diameters somewhat larger than the diameter of the channel. One or more pistons are attached to each of the plates. Explosive charges, or other suitable means, move the pistons to propel the plates across the channel to seal it off and stop the leak. Flanges may limit the pistons' movement. Gears can engage teeth on the pistons to withdraw the plates from the channel, to reopen it and allow the flow of oil or other fluid to resume. Plates may be withdrawn part way from the channel, to reduce and control the flow, without cutting it off completely.

Abstract: A combination blowout preventer and recovery device, comprising a lower part that is placed over a well pipe, and an upper part having a channel and plates to close it. The large end of the valve is placed over a well pipe through which fluid is flowing out. The small end of the valve is connected to the channel. A sleeve connected to the return pipe is placed over the well pipe. Positioning rings are attached to a high pressure pipe, that can fit inside the well pipe. Grinders remove matter from the well pipe. Pistons are attached to each of the plates. The pistons propel the plates across the channel to seal it off and stop the leak. Flanges may limit the pistons' movement. Gears can engage teeth on the pistons to withdraw the plates from the channel, to reopen it and allow the flow of fluid to resume.

Abstract: A system in some embodiments includes a back pressure valve. The back pressure valve includes a body, a plunger disposed internal to the body, and a friction member disposed about the exterior of the body. The friction member is configured to expand radially to contact an internal surface of a bore. In some embodiments, a method includes disposing a back pressure valve into a straight bore and expanding a friction member of the back pressure valve radially into contact with an internal surface of the straight bore.

Abstract: An extendable conductor stand allowing for rapid alignment and installation. The conductor stand having capacity to accept a BOP to protect against all blowouts, including behind the casing blowouts while drilling for “surface”. The extendable conductor stand having a diverter spool configured to allow secondary cementing or performing a “top job” with BOP protection in place.

Abstract: A locking assembly for seals within inner and outer members. The locking assembly includes a segmented tube with an inner surface that is segmented into a plurality of pieces cut in radial or reversed angles to allow assembling segments in a circumferential groove machined in the internal diameter of a housing. The housing has an internal diameter that is smaller than the outside diameter of the segmented tube. The segments that make up the segmented tubing are locked into place within the housing via a bushing or locking ring that match a profile on the inner surface of the segmented tube to lockingly engage. The bushing and segmented tube retain a lower inner seal in place and support an upper inner seal. The segmented design of the segmented tube allows for smaller diameter members to be used and minimizes leak paths.

Abstract: A device for connecting at least one electrical data and/or supply line to electrical sockets of a wired drill pipe is disclosed. One inventive aspect of the device comprises: a collet blocking plug axially insertable into and removable from a receiver end of the drill pipe and at least one collet. The collet is configured to be interlocked with the drill pipe in a locking position and be released from the drill pipe in a release position. The collet is axially displaceable from the collet blocking plug between the locking position and the release position. The collet blocking plug is axially insertable into and removable from a receiver end of the drill pipe.

Abstract: A wellhead assembly having an outer tubular, an inner tubular inserted into the outer tubular, an annular space between the inner and outer tubulars, a lock ring in the annular space, and an activation ring that axially strokes between the lock ring and one of the tubulars. The lock ring selectively locks together the inner and outer tubulars when the activation ring slides between the lock ring and the one of the tubulars. The surface of the activation ring that contacts lock ring is contoured so that an interface surface between the activation ring and lock ring when the lock ring is in its locked position, is offset an angle from an axis of the wellhead that is less than an offset between the axis of the wellhead and an interface surface between the activation ring and lock ring when the activation ring is stroking downward.

Abstract: An improved method is provided, for pumping fluids, such as water and/or hydrocarbons, from a subterranean formation or reservoir, through use of a cranked rod pumping (CRP) apparatus for imparting reciprocating substantially vertical motion to a rod of a sucker-rod pump having a pump stroke. The CRP apparatus includes a motor driven cranked mechanical actuator arrangement. The cranked mechanical actuator arrangement includes a substantially vertically moveable member attached to the rod of the sucker-rod pump for imparting and controlling vertical motion of the rod of the sucker-rod pump. The actuator arrangement may include pneumatic counterbalancing.

Abstract: There is provided a frac adapter configured to couple a frac tree to a wellhead component. The frac adapter may couple the frac tree to a casing head without a tubing head, thereby enabling the well to be fractured before the tubing head is installed. As a result, the tubing head used in well production may be pressure-rated for production pressures rather than for fracing pressures. The frac adapter may be coupled to or integral with the frac tree. In addition, a union-nut coupling may be employed to quickly and easily assemble and disassemble the frac adapter from the wellhead component, such as the casing head. The union-nut coupling may further enable the components to be pressure-tested before the fracturing process is initiated.

Abstract: Wellhead assemblies, seal assemblies, and methods of locking down an annulus seal disposed within an annulus between outer and inner wellhead members, are provided. A seal assembly is positioned in an annulus. An energizing member is axially translated downward to energize an annulus seal element and outwardly radially compress a high-strength lockdown member into contact with an inner diameter surface of a wellhead member. The wellhead member can include a set of wickers. During compression, the outer diameter surface of the lockdown member is plastically deformed onto the set of wickers.

Abstract: A method for controlling and coordinating the operation of a lifting device and a tongs device in removing and disassembling and/or installing and assembling a series of elongate members disposed within a wellbore involves sequentially sensing the presence of a series of joints and automatically triggering the lifting device and tongs device in response thereto. In some examples, the method senses the location of an upper joint to determine when the lifting device should begin decelerating prior to stopping the ascent of a lower joint at a target elevation. In some examples, the method includes control means for automatically skipping various joints.

Abstract: A seal assembly between a wellhead housing having a bore and a casing hanger, has an inner seal leg for sealing against hanger and an outer seal leg for sealing against housing. An extension extends downward from outer seal leg and is connected to a nose ring having a downward facing shoulder that rests on the hanger shoulder to provide a reaction point for setting operations. A lock ring is retained within interior portion of the nose ring. An upward facing shoulder formed on an upper portion of nose ring contacts the lower surface of the inner seal leg. The shoulder prevents the downward deflection of the inner leg and eliminates buckling due to Poisson effect from the resulting axial force due to growth of the seal legs during setting operations. The shoulder thus prevents crooked or twisted setting of the seal to prevent plastic strain in the seal.

Abstract: A top drive guide system comprising first and second rail sections axially aligned to form a top drive guide rail. A locking member is coupled to the first rail section and is movable between a locked position and an unlocked position. A locking surface is disposed on the second rail section and is operable to engage the locking member when the locking member is in the locked position. An actuator is coupled to the locking member and is operable to move the locking member from the locked position to the unlocked position.

Abstract: A wellhead seal assembly that forms a metal-to-metal seal between inner and outer wellhead members. A seal member has inner and outer seal legs separated by a slot. A locking ring is positioned in the outer seal leg and has wickered sections, where each of the wickered sections protrude through a window in the outer seal leg of the seal member. An energizing ring has an upper tapered surface that is oblique to an axis of the annular energizing ring and extending laterally from the axis over a portion of the locking ring and a lower tapered surface that is oblique to and extending laterally from the axis. As the energizing ring is moved into the slot, the upper tapered surface engages an inner surface of the locking ring, and the lower tapered surface engages an inner annular wall of the slot.

Abstract: A well apparatus system that includes a wellhead, a tree, a tubing hanger, a tubing spool that is located between the wellhead and the tree, and a production isolator surrounded by the tree and the tubing spool. The tree component of this system can include a vertical or horizontal tree. More importantly, this system can be constructed in a number of different sequences. In addition, this well apparatus system allows for installation, retrieval, and/or work-over the tubing hanger and associated completion system without disturbance of the tree. The presented system also allows for installation and retrieval of the tree independent of the tubing hanger and associated completion system. Some embodiments can include valve-type mechanisms to serve as production environmental barriers. These mechanisms are integral to the production isolator.

Abstract: An outer wellhead member has a bore with a first profile portion and an annular recess. A tubular inner wellhead member with a centralizer/overpull ring is lowered into the outer wellhead member. The centralizer/overpull ring is biased to expand outward to engage the bore of the outer wellhead member to center the inner wellhead member within the bore as the inner wellhead member is lowered through the bore. The recess of the outer wellhead member is adapted to receive the centralizer/overpull ring and oppose axial movement of the centralizer/overpull ring to enable an upward test pull of the inner wellhead member.

Abstract: Fluid circulation valve is provided for use with a well drilling operation, so that a drill joint may be added to or removed from the drill string while continuously circulating fluid into the well. Valve housing has a central flow path therein, a housing side port, and upper and lower threaded connectors for engagement with the drill joint and the drill string, respectively. A rotatable ball is positioned within the flow path in the valve housing and a port in the ball is in fluid communication with the housing side port when the ball is closed. A coupling is provided for engaging the valve housing and sealing between an interior of the valve housing and the radially external flow line, which passes fluid into the well when a drill joint is being connecting to the upper end of the valve.

Abstract: A fill up and circulation tool having an elongate body with an insertion section adapted for insertion into a tubular member, a base section adapted for engagement with a top drive, and a gauge section having a diameter less than that of the base section. A packer cup assembly and at least one spacer can be adjustably associated with the gauge section, the packer cup assembly being positionable at a plurality of locations along the gauge section by placing the packer cup assembly and one or more spacers relative to one another in a desired configuration, such that the packer cup assembly and one or more spacers occupy substantially all of the gauge section. The spacing and configuration of the packer cup assembly along the gauge section can be selected depending on the dimensions or type of top drive, elevator, bails, or other equipment at a worksite.

Abstract: An assembly supports a control line of a downhole tool, such as a downhole deployment valve. The tool deploys on casing and has a control line extending from the wellhead to the tool. To support the line separately from any casing hanger, a split bowl disposes around the casing and lands on a shoulder in the head. A port in the bowl has one opening that aligns with a side port in the head. Another opening of the bowl's port connects to the control line that extends to the downhole tool. A section of the control line from the split bowl can be flexible to help prevent kinking or breaking of the line during installation procedures. A hanger disposes on another shoulder in the head uphole from the bowl. The hanger supports the casing in the head separate from the bowl's support of the control line.

Abstract: In accordance with an exemplary embodiment, a tubing hanger having an angled auxiliary bore is provided. The auxiliary bore may receive a penetrator for a cabling system that powers a submersible pump. The auxiliary bore is angled with respect to the production bore of the tubing hanger. As a result, the penetrator exits the lower end of the tubing hanger at a location relatively close to the production tubing. This facilitates the use of a smaller-diameter production casing or casing hanger, in turn helping to reduce potential costs, for instance.

Abstract: The system includes a modular drum unit disposed in a first skid. The modular drum unit may include a drum and a winch. The system also includes a power pack assembly disposed in a second skid. The power pack unit may comprise a power source. The system also includes a cable assembly for electrically coupling the modular drum unit to the power pack unit. The cable assembly includes a power connector with a connector type incorporating design constraints from both the modular drum unit and the power pack unit.

Abstract: removable blowout recovery valve. The large end of the valve (or funnel) is placed over a well pipe (or other pipe) through which oil (or other fluid) is flowing out. The small end of the valve is connected to a return pipe. A high pressure pipe with a smaller diameter is inserted into the well pipe. A sleeve connected to the return pipe is placed over the well pipe. A locking collar is attached to the sleeve. Positioning rings are attached to the high pressure pipe, that can fit inside the well pipe. A sharp edge extends from the sleeve, by which irregularities in the well pipe can be cut. Lasers or other cutting devices are attached to extension arms, that can also cut irregularities in the well pipe. The slope of the valve can be changed. The valve can be removed and raised with the aid of floats.

Abstract: To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Abstract: A system, including a wellhead system, and a flow control system coupled to the wellhead system, wherein the flow control system comprises, a flow control device including a housing, a flow path through the housing from an inlet to an outlet, and a flow control element disposed in the housing along the flow path, and an actuator mounting assembly coupled to the flow control device, wherein the actuator mounting assembly is configured to selectively mount one of a manual actuator and a powered actuator to actuate the flow control element of the flow control device, without taking the flow control system offline.

Abstract: A running tool for delivering a hanger into a wellcomprises a main body. In addition, the running tool comprise an attachment means for connecting a hanger to the main body. Further, the running tool comprises a sleeve having an external profile and being rotatably mounted around the main body. The sleeve has engagement means for releasably connecting the sleeve to a landing ring mounted via a thread on the hanger such that rotational movement of the sleeve causes rotational and thus axial movement of the landing shoulder on the hanger.

Abstract: A wellhead seal assembly that forms a metal-to-metal seal between inner and outer wellhead members. A bi-metallic U-shaped seal with legs having a low yield metal on the outer portions. During installation of the seal assembly, the legs of the seal are forced outward against the surfaces of the wellhead members, by pressurization of a interim non-metallic seal which forces a wedge into the U-shaped seal, causing localized yielding of the low yield metal to fill defects on wellhead member surfaces.

Abstract: A transportable rig apparatus provides for well completion operations while also providing a rig apparatus that readily resists or negates the effects of dynamic wind forces or other weather phenomenon. More particularly, the transportable rig apparatus provides a mast assembly that can extend in a generally vertical direction, e.g. perpendicular to the rig carrier and/or ground surface, such that the rig can be placed directly adjacent to a wellbore, the mast assembly providing a mast apparatus that readily resists or negates the effects of strong winds or other weather phenomenon.

Abstract: A completion system and method adapted for use in wells having long lateral boreholes includes a mast assembly, a pipe handling mechanism, a pipe arm, a pipe tub, a pump/pit combination skid, a rig carrier, and a control system. The mast assembly can extend in a generally vertical direction, e.g., perpendicular to the rig carrier and/or the earth's surface, such that the rig can be placed directly adjacent to a wellbore, and the top drive or a similar drive system can be engaged with and move along the mast while remaining above the wellbore.

Abstract: A method and apparatus for aligning a wellhead or BOP stack with a mast assembly comprising a sensor which provides an initial alignment between a mast and a wellhead or BOP stack. A mast assembly is transported to a well site by a rig carrier which positions the mast assembly adjacent a wellhead, or BOP stack. The mast assembly is raised to an upright position whereby a rear portion of the mast extends over the wellhead. Sensors mounted to the top drive, crow, well head, or mast can be used to align the mast with the wellhead.

Abstract: A rig system and method is provided for use with multiple wellheads in close proximity on a wellsite. A mast assembly is mounted to a rig carrier for alignment with a first wellhead. A pipe handling system is mounted to a skid having a pipe moving member mounted to the skid. A rig platform for use with the mast assembly is vertically moveable for accommodating a second wellhead in close proximity to the first wellhead while allowing operators to work within the mast assembly.

Abstract: An assembly for use on a wellhead includes a tree body including an internal main bore arranged in use to be aligned with the bore of a wellhead housing; the tree body including a lateral bore extending through the tree body from the internal bore; the tree body further including means for connecting to a connector so as to align the internal bore of the tree body with an internal bore in the connector, in use the tree body and the connector together forming a horizontal tree. The tree body may include one or more integrally formed bores and valves to provide fluid flowpaths for the annulus and/or cross-over functions. A wellhead assembly including the tree assembly is also provided.

Abstract: A riser assembly and method of forming where the riser assembly is made up of tubular members joined together. A metal spray process applies a layer of cladding onto ends of the tubular members and the ends are threaded to form respective box and pin configurations. Grooves are provided onto the surface of the tubular members beneath where the metal spray is applied for enhancing adhesion of the cladding and tubular members. The layer of cladding provides sufficient material so that threads may be selectively formed on the outer or the inner surface of the tubular members.

Abstract: A flange assembly and method for securing the downhole tubing string and packer to a blowout preventer is disclosed. The application is particularly useful for high pressure fluid applications downhole such as hydraulic fracking.

Abstract: A system and methodology for controlled entry of a tubing string, and cable adjacent thereto, into a wellbore. A stationary housing is fit to a wellhead and has a bore in communication with the wellbore. The cable can be laterally displaced from the bore into a cable access formed into the housing's side wall for fitting a sealing assembly to the bore and engages a sealing surface therein. The sealing assembly seals tubulars passing therethrough. The cable access interrupts the sealing surface. A cable bypass sub is fit to the cable access and permits the cable to extend sealingly from above the sealing surface to the wellbore wherein the cable bypasses the sealing assembly and sealing surface. A seal reconstitutes the interrupted portion of the sealing surface at the cable access.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: Wellhead control line deployment involves replacing the seat/retainer plate of a master valve of the wellhead with a modified retainer plate. The retainer plate defines a first port communicating from a central opening of the plate to outside the plate. A modified bonnet installs on the master valve, and the bonnet has two ports, one communicating with the first port in the retainer plate and the second communicating with a needle valve port. The communication ports are linked by a tube with outside diameter seals that inserts between the retainer plate and the bonnet. A control line hanger can be retained by locking into an adapter sleeve or directly in the back-pressure valve threads of a tubing hanger. The adapter sleeve can be attached to the retainer plate or have a collet to snap into the back-pressure valve threads of the tubing hanger.

Abstract: Described herein is a modular, adjustable system for distributing fluids to one or more wellbores. The system is readily configured and assembled at a well site, and allows for one portion of the system to be isolated for service or repair while the remainder of the system continues to operate. The system includes a plurality of pump skids having both a distribution junction in fluid communication with inlets to of plurality of pump trucks and an exit junction in fluid communication with outlets of the plurality of pump trucks.

Abstract: A connector to secure a blow out preventer to a casing head of a well or wellhead or other tubing and a method of securing a blow out preventer to the well tubing utilizing the connector. The connector may be configured to secure the blow out preventer adapter to the well tubing and provide, within fifteen minutes, a seal operable to withstand ten thousand pounds per square inch of pressure. The connector may include both a hydraulically operated locking segment and a separate mechanical locking segment, and wherein both locking segments may be transitioned from a fully retracted position to a fully locked position within fifteen minutes. The connector may be configured to accommodate up to ten degrees of misalignment between the blow out preventer and the tubing.

Abstract: Methods and apparatus are provided for running tubulars into and out of a wellbore. A tubular handling system having a tubular gripping apparatus having a gripping mechanism and a sensor adapted to track movement of the gripping mechanism, wherein the sensor sends a signal to a controller when the gripping apparatus is in a position that corresponds to the gripping apparatus being engaged with the tubular.

Abstract: A change-out flange suited for use at an existing head casing of an oil or gas production well. The change-out flange is devised to replace standard hammer caps atop a well casing. By the present invention, with comparative ease a variety of wellhead equipment can be removably and interchangeably secured to the wellhead using an existing casing bowl or spool. The change-out flange has a casing hub that can be screwed unto a known casing bowl, and an integral connection flange provided with a plurality of connection holes arrayed in a manner consistent with the connection hole arrays of an assortment of conventional wellhead devices such as valves. A variety of well head devices thus can be more readily removed from, and securely replaced upon, the change-out flange. Lockdown pins are insertable into the change-out flange in a manner which secures the tubing hanger in place within the casing bowl.

Abstract: A method and apparatus are provided for installing control lines and pipe into a well. The pipe-holding spider that is normally mounted on the rig floor is adapted for easy disassembly and reassembly when the pipe slips within the spider are not engaged with the outer surface of the pipe string so that upon disassembly, a control line guide becomes vertically movable. The control line guide is adapted for being controllably elevated to a distance above the rig floor, thereby providing personnel access to a portion of the length of the pipe string below the elevated control line guide and above the rig floor for securing control line to the pipe string using a fastener.

Abstract: A method for operating a linear rod pump to pump fluids, such as water and/or hydrocarbons, from a subterranean formation or reservoir, include a linear rod pump having a mechanical rack and pinion drive arrangement, adapted for attachment to a pumping mechanism, such as the polished rod at the top of a rod string in a hydrocarbon well. The rack gear, of the rack and pinion drive arrangement, is adapted for connection to, and movement with, the polished rod. The pinion gear does not translate with the rack gear, and is driven by a reversible motor for affecting up and down reciprocating motion of the rack gear and pumping mechanism. Some forms of the invention include a compressible gas counter-balance arrangement. Some forms of the invention include an electronic drive configured for dealing with electric power generated by the motor during a portion of the pumping cycle.

Abstract: A locking door assembly, blowout preventer and method are provided. The blowout preventer is for sealing about a tubular extending from a wellbore of a wellsite. The blowout preventer includes a housing having a bore and a channel therethrough. The tubular is positionable through the bore and engageable therein. The blowout preventer also includes a door assembly including a door slidably positionable along an axis of the channel and providing selective access to the channel, and a lock. The lock includes at least one locking member having at least one raised portion extending along the door assembly in a direction transverse to the axis of the channel. The locking member is extendable into at least one corresponding receptacle of the housing and movable therealong between an unlocked and a locked position whereby the door assembly is selectively retractable from the housing.

Abstract: A connector (1) for connecting components of a subsea system, the connector comprising male and female components (3, 2), guide means (11) for assisting preliminary orientation of the male component within the female component and means (18; 20; 21) for drawing the male component into the female component and latch means (22) for securing the male component within the female component.

Abstract: A mobile manifold assembly of a fluid system for providing fluid to a wellsite during well construction. The fluid system includes auxiliary components including at least one fluid source, mixer and high pressure pump. The manifold assembly includes a modular manifold and a mobile frame. The modular manifold includes manifold pumps, valves and pipes integrated together for transport. Connector portions of the pipes extend from the modular manifold in an arrangement corresponding to an arrangement of the auxiliary components to define a plug-in configuration therebetween such that the connector portions of the pipes are positionable in alignment with the auxiliary components for direct and removable connection therewith. The manifold pumps and valves are positioned about the pipes to selectively pump the fluid. The modular manifold is securable to a base of the mobile frame whereby the modular manifold is transportable to the auxiliary components for operable connection therewith.

Abstract: A wellhead assembly includes a casing head and a tubing head that is landed within the casing head when the tubing head is landed. The casing head has top and bottom ends, and its bottom end is coupled to surface casing. The tubing head also has top and bottom ends, and its bottom end is coupled to an additional casing string, such as production casing. The tubing head can be landed on the casing head through a blowout preventer.

Abstract: A device for a top drive drilling machine, in which a drive shaft (14), which is arranged for releasable connection to a drive (12) and to a first end portion (51) of a drill pipe (5), is provided with a center bore (141) extending therethrough and arranged for fluid communication between the drilling mud plant (6) and a fluid bore (53) in the drill pipe (5). First and second releasable, drive-shaft-surrounding, respectively drill-string-surrounding, pressure seals (1311c, 1321) and a valve (133) which is arranged to provide, in an open position, a passage (1331) for the drill pipe (5) or drive shaft (14), form a first and a second chamber. A drilling mud inlet (1323) is arranged for the second chamber (132) and is arranged for fluid communication between the drilling mud plant (6) and connection housing (13). A method for the continuous supply of drilling mud to a drill string (4) by the use of the drilling machine.