Abstract: A protective cap assembly for a subsea equipment mandrel or hub, including a protective cap body with a top plate and a cylindrical sidewall. The protective cap body may further include a primary inlet port, a first annular groove, a secondary inlet port, a second annular groove, and one or more secondary outlet ports. A primary seal may be disposed in the first annular groove to sealingly engage the mandrel or hub, and a secondary seal may be disposed in the second annular groove to sealingly engage the mandrel or hub. The protective cap assembly may further define at least in part primary and secondary chambers configured to fluidly communicate, and the secondary chamber configured to fluidly communicate directly or indirectly with the external subsea environment.

Abstract: A method and apparatus are provided for securing a protective sleeve or wear sleeve to a rotary component which is rotatable relative to a rotary seal, such that the wear sleeve is in relatively rotating sealing engagement with the rotary seal. The wear sleeve is secured to the shaft by wedging a lock ring between the wear sleeve and the shaft. Wedging action of the lock ring can be effected by wedging formations, such as tapered surfaces, configured for causing wedging of the lock ring in response to operator-induced axial movement of the lock ring relative to the shaft and/or the wear sleeve. Wedging of the lock ring can be effected by cooperating screw threads on the lock ring and the wear sleeve, so that an operator can tighten the sleeve on the shaft by application of torque thereto.

Abstract: A pressure control device can include an outlet, an inlet secured to well equipment, and a swivel mechanism that permits relative rotation between the outlet and the inlet in an unlocked configuration and prevents relative rotation between the outlet and the inlet in a locked configuration. A lock device of the swivel mechanism can include circumferentially distributed teeth, and an engagement member that engages at least one of the teeth in the locked configuration. A method of operating a pressure control device can include securing an inlet of the pressure control device to well equipment, rotating an outlet of the pressure control device about a longitudinal axis of the inlet, locking a swivel mechanism of the pressure control device, thereby preventing rotation of the outlet relative to the inlet, and sealing off an annulus surrounding a tubular string extending through the inlet.

Abstract: A subsea completion system for a subsea well includes a tubing spool including an internal bore formed therethrough and a tubing hanger movable into a landed position within the internal bore of the tubing spool. The tubing hanger includes a production bore formed therethrough, an auxiliary passage formed therethrough outside of the production bore, and a valve in fluid communication with the auxiliary passage to control the flow of fluid through the auxiliary passage.

Abstract: Embodiments of the present disclosure are directed toward a seal assembly comprising a main body comprising a production fluid port configured to align with a production fluid bore of a tubing spool of a mineral extraction system, a first annular seal supported by the main body and disposed on a first side of the production fluid port, and a second annular seal supported by the main body and disposed on a second side of the production fluid port, wherein the seal assembly is configured to be disposed in an annular region between a hanger and the tubing spool of the mineral extraction system, the first annular seal and the second annular seal are configured to isolate the production fluid port from the annular region, and the seal assembly is configured to be removed from the tubing spool without the hanger.

Abstract: A wellhead assembly is provided. In one embodiment, the wellhead assembly includes a universal frac sleeve assembly for isolating portions of a wellhead assembly from pressurized fracing fluid. The universal frac sleeve assembly may include an inner sleeve, an outer sleeve, and a seal. Axial movement of the inner sleeve relative to the outer sleeve causes the seal to expand radially, thereby forming a seal within the wellhead assembly.

Abstract: A blowout preventer assembly comprising a blowout preventer and control apparatus, the blowout preventer comprising a housing a sealing element and a fluid pressure operated actuator mounted in the housing, the actuator 18 dividing the interior of the housing into two chambers, namely an open chamber and a close chamber, substantially preventing flow of fluid between the two chambers, and being movable, by means of the supply of pressurized fluid to the close chamber, to urge the sealing element into sealing engagement with a drill pipe extending through the blow out preventer, the control apparatus including a close line which extends from the exterior of the housing to the close chamber, and a source of pressurized fluid which is connected to the close line, wherein the source of pressurized fluid is located adjacent to the housing.

Abstract: A well system includes an annular barrier separating the tubing-casing annulus into an upper annulus and a lower annulus and a barrier valve coupled with the annular barrier, the barrier valve permitting one-way fluid communication from the upper annulus to the lower annulus. The annular barrier may include dual cup packers.

Abstract: A wellhead assembly is provided. In one embodiment, the wellhead assembly includes a universal frac sleeve assembly for isolating portions of a wellhead assembly from pressurized fracing fluid. The universal frac sleeve assembly may include an inner sleeve, an outer sleeve, and a seal. Axial movement of the inner sleeve relative to the outer sleeve causes the seal to expand radially, thereby forming a seal within the wellhead assembly.

Abstract: A ram blowout preventer for sealing a well, the ram blowout preventer including a body having a cavity with a recess; a ram block configured to move inside the cavity; a top seat disposed in the recess and configured to seal the well when in contact with the ram block; a movable lock ring extending inside a groove of the body and a corresponding groove of the top seat and configured to move inside the groove of the body, along a direction substantially parallel to the well; a first seal extending inside a groove of the top seat and configured to contact the body and the top seat; and a second seal extending inside a groove of the ram block and configured to contact the ram block and the top seat. A width of the groove of the body is larger than a width of the lock ring by a predetermined value, which is larger than normal tolerances, and a distance from a centerline of the well to the first seal is larger than a distance from the centerline of the well to the second seal.

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.

Abstract: Return flow diverters are provided for which are adapted to allow return flow during cementing of a liner for a well. The return flow diverter comprises a cylindrical body adapted for installation in a well as part of the liner. The cylindrical body has a fluid port therein adapted to allow fluids displaced by a cementing operation to flow from an annulus between the liner and the well into the cylindrical body. The return flow diverter also comprises a cover supported on the cylindrical body for movement from an open position, in which the port is open, to a closed position, in which the port is closed by the cover, a transmission disposed within the cylindrical body and defining a cylindrical passageway adapted to accommodate a tubular conduit.

Abstract: A hydraulic lubricator assembly includes a spool for enclosing a downhole tool, wherein the spool comprises an upper end and a lower end. The hydraulic lubricator assembly further includes a pressure isolation connector attached to the upper end of the spool, wherein the pressure isolation connector includes a lower packing gland and an upper packing gland. A hydraulic assembly is positioned above the pressure isolation connector, wherein the hydraulic assembly comprises a rod connected to the downhole tool, and wherein the hydraulic assembly lowers the downhole tool into the wellbore.

Abstract: A well head lubricator assembly including an elongated rigid tubular body defining an interior chamber open at a lower end to receive a plunger at a well head. The plunger is slidably positioned within the chamber in response to forces or loads acting thereon and has a seat arranged toward an upper end thereof. An upper end of the tubular body is closed. An axially elongated one-piece thermoplastic ether ester elastomer spring is slidingly positioned within the interior chamber of the tubular body. One end of the spring is seated on the seat of the plunger. The spring defines an elongated bore opening to opposed ends thereof. Moreover, the spring is provided with a plurality of axially spaced flange sections along a length thereof for guiding the spring for endwise sliding movement on an inside diameter of the tubular body. Any two flange sections on the spring are axially separated by an energy absorbing section for allowing the spring to react to energy imparted to the plunger.

Abstract: A flow regulator includes a flow regulating part configured to receive at an inlet a working fluid at a first pressure and to release the working fluid at an outlet at a second pressure; a slide provided inside the flow regulating part and configured to move along an axis to reduce the pressure of the working fluid; a control part attached to the flow regulating part, the control part including a chamber; a spring housing provided in the chamber and connected to the slide though a shaft, the spring housing configured to move the slide along the axis; a cap provided in the chamber and facing the spring housing, the cap being configured to have plural blind holes; and plural pins extending along the axis and attached to the spring housing, the plural pins being configured to enter the plural blind holes.

Abstract: The disclosure provides a fracturing isolation sleeve for a wellhead assembly including a fracturing adapter and tubing head. In at least one embodiment, the sleeve can telescopic to different lengths to fit different assemblies without necessitating switching the sleeve or portions thereof. The sleeve can be coupled to the wellhead assembly by threaded and non-threaded connections. The sleeve upper portion can be threadably engaged with the wellhead assembly, and/or the sleeve lower portion can be threadably engaged with a packoff bushing rotationally coupled to the wellhead assembly through an anti-rotation mechanism. Further, the sleeve can include a retaining nut to be threadably engaged with the wellhead assembly without necessarily rotating the sleeve upper or lower portions. The sleeve can be also coupled with the wellhead assembly through a mandrel coupled to the sleeve having an actuating cam surface to actuate a lock ring with the wellhead assembly.

Abstract: Disclosed is a tubing system for transporting a gas-liquid flow from a well to a production platform or processing facility. It includes a dual pathway section between the well and the production point having a first tubing portion and a second tubing portion. The second tubing portion includes a plurality of parallel channels so as to divide the multi-phase flow into a plurality of flows through individual channels. This is done to reduce flow slippage of the lower viscosity portion of the flow, which may lead to inefficiencies in flow characteristics, and often, undesirable cyclical variations in pressure and fluid volume. This is especially useful in inclined portions of the petroleum flow pipe system and along hilly terrain. The first round tubing portion is used for transporting the gas-liquid flow as well as for maintenance purposes, such as for pigging, fishing or coiled tubing operations.

Abstract: A subsea well tubular member has an axial passage with upper and lower retrievable plugs releasably mounted in the passage, the plugs having ends facing each other. A cavity is formed on one of the ends of one of the plugs. A movable barrier is mounted sealingly over the cavity, the barrier being movable repeatedly between inner and outer positions in response to temperature changes. The inner position reduces a volume of the cavity and increases a volume of a trapped fluid space between the ends of the plugs. The outer position increases the volume of the cavity and decreases the volume of the trapped fluid space. The barrier has two metallic layers with different coefficients of expansion.

Abstract: A retrievable frac mandrel and a well control adapter are used to efficiently accomplish well completion, re-completion or workover. The retrievable frac mandrel is inserted in a tubing head spool of a well to be completed, re-completed or re-worked. The well control adapter is mounted to a top of the tubing head spool and seals off against a top of the retrievable frac mandrel. After well completion, re-completion or workover is completed, the frac mandrel can be retrieved from the tubing head spool without killing or plugging the well.

Abstract: A well head barrier assembly (1, 2, 3) including a termination of an instrument tube (9) installed in a well and a primary pressure barrier (3) for the well pressure comprising a tool (10) arranged for being pushed into a passage (5) in which the instrument tube (9) is arranged. The closing of the passage (5) provides an additional secondary pressure barrier in the well head, thus enabling re-establishment of a double pressure barrier following a breakage of the instrument tube (9).

Abstract: A shock absorber for use with a lubricator assembly comprises a body made substantially of a polymer material. An end of the body is supportable by a cup. Upon plunger strike, the cup can travel upward in the lubricator assembly and cause the polymer body to deform and dissipate a force of impact caused by the plunger. The body can resiliently compress and expand to substantially an original form. Equalization slots on the body can enable fluid carried to the surface by a plunger to flow from the lubricator assembly.

Abstract: Methods and systems for investigating downhole conditions are described. One method comprises inserting a tubular into a wellbore, the tubular comprising a tubular section having upper and lower fluid injection ports, and having a thermally insulated fiber optic cable section positioned inside the tubular extending to the upper fluid injection port, and a non-insulated fiber optic cable section positioned outside of the tubular section and extending at least between the upper and lower fluid injection ports; positioning the tubular section having upper and lower fluid injection ports near a suspected thief or pay zone; injecting a fluid through the upper fluid injection port; determining a first differential temperature profile between the upper and lower fluid injection ports; injecting a fluid through the lower fluid injection port; and determining a second differential temperature profile at least between the upper and lower fluid injection ports.

Abstract: A welihead assembly to seal to a production casing including one or more pressure-containing wellhead body members defining a vertical bore, with the lowermost of the wellhead body members sealing to the production casing. A fracturing isolation tool is sealed in the vertical bore of the wellhead body members above the production casing, and forms a pressure barrier profile in its internal bore. A removable protector sleeve is located at least partially within the fracturing isolation tool to seal, protect, isolate and cover the pressure barrier profile against a fracturing pressure and a fracturing fluid. After fracturing the protector sleeve is removed and a pressure barrier is sealed in the pressure barrier profile of the fracturing isolation tool. The invention also extends to the method of isolating the wellhead body members and to the fracturing isolation tool assembly which includes the fracturing isolation tool and the protector sleeve.

Abstract: A safety valve system for removing down-hole tools from a coal-bed methane well. The system includes first and second horizontally opposed stuffer-blocks, a stuffer-box housing for housing the stuffer-blocks, a means for attaching said stuffer-box housing to a coal-bed methane wellhead, and a means for delivering fluid to move the stuffer-blocks between an open position and a closed position. In one embodiment, the safety valve system further includes a controller, at least one methane sensor, a stuffer-box position sensor, and a stuffer-block activation system. A control algorithm is stored on or in communication with the controller enabling the controller to control the position of the stuffer-blocks, moving the stuffer-blocks between an open and closed configuration, wherein the stuffer-blocks are maintained in an open configuration if the methane level is below a predetermined threshold level. The valve system may further comprise a free-rotating stripper-diverter atop of the valve system.

Abstract: Subsea lubricator device, comprising a blowout preventer assembly, a tool housing assembly and a stuffing box, intended to be located at a subsea Christmas tree, and methods of circulating fluids in a subsea lubricator. The device comprises a blowout preventer (40) and a lubricator (60). Along the entire length of the device a bypass (46, 66) is located. The bypass communicates fluid with the device via a fluid connection (72) at the upper end of the tool housing and via a valve assembly (51) at the bottom of the blowout preventer. This permits removal of gas or oil being present in the device by circulating the hydrocarbons in the well.

Abstract: A flow completion system for controlling the flow of fluid from a well bore comprises a tubing spool which includes a central bore that extends axially therethrough and a production outlet which communicates with the central bore. A tubing hanger is supported in the central bore and includes a production bore that extends axially therethrough and a production passageway that communicates between the production bore and the production outlet. A first closure member is positioned in the production bore above the production passageway, and a first metal seal is positioned concentrically between the tubing hanger and the central bore above the production passageway. In addition, a second closure member is positioned in the production bore above the first closure member, and a second metal seal is positioned concentrically between the tubing hanger and the central bore above the first seal.

Abstract: A subsea wellhead assembly has the capabilities of communicating from a tree assembly mounted on an inner wellhead housing to a casing annulus. A passage in the wellhead assembly extends within the bore of the wellhead housing from the casing annulus to the tree assembly. A portion of the passage is located within a casing hanger. The passage is opened and closed by a valve. The valve does not open the passage until the tree assembly is connected to the wellhead housing and a tubing hanger orientation sleeve lands in the wellhead assembly. The tubing hanger orientation sleeve actuates the valve when it lands to open the passage. When the passage is opened, the casing annulus is in fluid communication with the interior surface of the wellhead housing, which is in communication with the tree assembly.

Abstract: A flow completion system for controlling the flow of fluid from a well bore, the flow completion system comprising a tubing spool which includes a central bore that extends axially therethrough and a production outlet which communicates with the central bore; a tubing hanger which is supported in the central bore and which includes a production bore that extends axially therethrough and a production passageway that communicates between the production bore and the production outlet, the tubing hanger supporting a tubing string which extends into the well bore and defines a tubing annulus surrounding the tubing string; a first closure member which is positioned in the production bore above the production passageway; a first annular seal which is positioned between the tubing hanger and the central bore above the production passageway; wherein the first closure member and the first seal comprise a first pressure-containing barrier between the well bore and a surrounding environment; a second closure member which

Abstract: A flow diverter assembly for a tree, the flow diverter assembly having a flow diverter to divert fluids flowing through the production bore of the tree from a first portion of the production bore to the cap, and to divert the fluids back from the cap to a second portion of the production bore for recovery therefrom via an outlet, wherein the flow diverter is detachable from the cap to enable insertion of the flow diverter through the cap.

Abstract: A flow completion system comprises a tubing spool which is connected above a wellhead housing, a tubing hanger which is supported in the tubing spool and which includes an axial production bore and at least two conduits that each extend from the bottom of the tubing hanger to either the top or the outer diameter of the tubing hanger, and a gate valve assembly which includes an elongated body having a longitudinal bore extending therethrough, a plurality of gates slidably disposed in the longitudinal bore across respective flow passages which each extend laterally through the body between corresponding inlet and outlet ports, each gate being movable between an open position wherein an opening in the gate is aligned with its respective flow passage and a closed position wherein the opening is offset from its respective flow passage, an actuator for moving the gates simultaneously between a first position, wherein at least one of the gates is in its open position, and a second position, wherein the at least one

Abstract: A flow completion system for controlling the flow of fluid from a well bore, the flow completion system includes a tubing spool which includes a central bore that extends axially therethrough and a production outlet which communicates with the central bore. A tubing hanger includes a production bore that extends axially therethrough and a production passageway that communicates between the production bore and the production outlet and a first closure member which is positioned in the production bore above the production passageway. A first annular seal which is positioned between the tubing hanger and the central bore above the production passageway including first pressure-containing barrier between the well bore and a surrounding environment.

Abstract: A subterranean oil or gas well apparatus is provided. The apparatus includes a single-bore production tubing hanger arranged concentric with a wellhead. The tubing hanger includes a plurality of ports and channels arranged about the tubing hanger to give operators access to the production tubing annulus and provide chemical injection capability. The ports are closable by a sliding valve. The apparatus also includes annulus and production radial-bore stab assemblies between a christmas tree and an internal crossover assembly. The stab assemblies are extendable and retractable between the chirstmas tree and the crossover assembly to allow the retrieval and installation of each independently.

Abstract: A flow completion system for controlling the flow of fluid from a well bore, the flow completion system comprising a tubing spool, a tubing hanger supporting a tubing string which extends into the well bore and defines a tubing annulus surrounding the tubing string; a first closure member which is positioned in the production bore above the production passageway; a first annular seal wherein the first closure member and the first seal comprise a first pressure-containing barrier between the well bore and a surrounding environment; a second closure member which is positioned in the production bore above the first closure member; and a second annular seal wherein the second closure member and the second seal comprise a second pressure-containing barrier between the well bore and the environment; and wherein both the first and the second barriers are associated with the tubing hanger.

Abstract: A lubricator assembly for a well head of a gas-producing well includes an elongated rigid tubular body having upper and lower ends and a cylindrical interior chamber open at the lower end for receiving a leading end of a gas lift plunger at the well head, a removable end cap attached at the upper end of the tubular body, and an elongated polyurethane body having a cylindrical configuration and characteristics of a coil spring in that the polyurethane body can be resiliently compressed along its longitudinal axis and will spring back to substantially its original form. The polyurethane body is disposed in the tubular body between the removable end cap and the lower end of the tubular body such that upon arrival of the plunger at the tubular body the polyurethane body will be impacted by the force of the plunger and absorb the impact force.

Abstract: A flow completion system for controlling the flow of fluid from a well bore, the flow completion system comprising a tubing spool which includes a central bore that extends axially therethrough and a production outlet which communicates with the central bore; a tubing hanger which is supported in the central bore and which includes a production bore that extends axially therethrough and a production passageway that communicates between the production bore and the production outlet, the tubing hanger supporting a tubing string which extends into the well bore and defines a tubing annulus surrounding the tubing string; a first closure member which is positioned in the production bore above the production passageway; a first annular seal which is positioned between the tubing hanger and the central bore above the production passageway; wherein the first closure member and the first seal comprise a first pressure-containing barrier between the well bore and a surrounding environment; a second closure member which

Abstract: A pair of ram blocks are provided such that when they are actuated hydraulically to move together, they present an opening which has a series of gripping members downwardly biased. Removal of tubulars or tools from the well bore works against the bias to retract the grippers so that removal can be accomplished. However, if there is an accidental release, the bias pushes the grippers toward the tubular or tool to grip it to prevent loss into the well bore. The ram blocks can be retracted for run-in to the well bore.

Abstract: A tubing hanger incorporates a flow control valve that is ordinarily found in a horizontal christmas tree. A branch passage forming a production fluid outlet has a mouth that intersects with a vertical production bore. A valve closure element in the form of a rotatable sleeve or saddle is disposed in the bore for co-operation with a seat disposed in the branch passage. Rotation of the sleeve, e.g. by a shaft extending through a crown plug, brings a hole into or out of alignment with the seat to control production fluid flow. In other embodiments, the sleeve is axially movable.

Abstract: A drilling head used to seal around a drill pipe while drilling is employed in a subsea location. The drilling head has an inner body located within an outer body. At least one bearing is located between the outer body and the inner body for facilitating the rotation of the inner body relative to the outer body. A seal mounted to a lower portion of the inner body seals around the outer surface of the drill pipe. While lowering the drilling head to the wellhead, a support attached to the drill pipe is inserted into a skirt which surrounds a portion of the seal. The skirt and support are releasably connected using a J-slot mechanism. An inner annulus and an outer annulus are located between the inner and outer bodies, the annuluses containing a lubricating fluid. Helical vanes are located within the inner annulus and affixed to the inner body. The vanes rotate with the inner body for circulating the fluid through the inner and outer annuluses.