Abstract: Embodiments of a method include connecting an inner end of a base of a fluid coupling assembly to an outer surface of a manifold of a hydraulic fracturing system. The base includes an outer end opposite the inner end and a through-passage extending from the outer end to the inner end. In addition, the method includes inserting a coupling adapter into the through-passage from the outer end to compress the coupling adapter into the through-passage and to position a connection device of the coupling adapter outside of the through-passage at the outer end.

Abstract: An apparatus for installation to a subsea equipment mandrel or hub, including a body having a cylindrical sidewall defining one or more receptacles and a locking system to couple the body to the mandrel or hub. The locking system may include one or more locking assemblies received within a respective receptacle and coupled to the cylindrical sidewall. Each locking assembly may include a locking body, a locking collar, an annular seal, an actuator, and a locking pin. The annular seal may be seated within an annular groove and configured to engage the shoulder of a receptacle in a sealing relationship, and the locking collar may couple the locking body to the cylindrical sidewall. The actuator may be adjustably coupled to the locking body and configured to move radially. A locking pin may be configured to selectively engage the angled shoulder surface of the mandrel or hub.

Abstract: A connector block having a single piece body may be configured for use in a Christmas tree. The connector block may include an axial bore formed therethrough, one or more valve chambers, passing fully through the connector block and intersecting the axial bore, one or more frac bores, extending from an outer surface of the connector block to the axial bore; and, one or more wing bores, extending from the outer surface of the connector block to the axial bore.

Abstract: A well head cover includes a polymeric body integrally including a tubular shaped main body portion. A tubular shaped mounting portion extends from the main body portion. A tubular shaped discharge portion is connected to the main body portion and is oppositely directed with respect to the mounting portion. A first discharge tube bore is created through a first end wall provided in the discharge portion. A second end wall is provided in the mounting portion. The second end wall has an end wall portion through which a second discharge tube bore is created. An axial centerline of the second discharge tube bore is coaxially aligned with an axial centerline of the first discharge tube bore. A pipe extending through the well head cover has a diameter adapted to provide a sliding fit with the first and second end walls at the first and second discharge tube bores.

Abstract: A tree cap has a wedge type annular metal seal for capping and sealing a subsea tree and associated methods to energize the same. The tree cap includes a cam element having a lower end with a conical profile adapted to be disposed within a respective bore of the subsea tree. The cam element moves along an axis of the bore. The annular metal seal is disposed on an outer diameter of the cam element so that the cam element may compress the annular metal seal against an actuation member to seal the bore of the subsea tree. The tree cap includes a housing adapted to be disposed on and secure to the subsea tree. The housing carries the cam element and exerts an axial force on the cam element to deform the annular metal seal into sealing engagement between the tree cap and the subsea tree.

Abstract: A cap for protecting a sealing surface of a hub of a subsea device includes an equalization valve and a fluid conduit. The equalization valve includes a valve body having a pressure equalization conduit, a sleeve disposed about the valve body and having a port allowing fluid communication across the sleeve, and a valve spring configured to bias the sleeve to a closed position. The sleeve is configured to move to an open position in response to a force that depresses the sleeve and causes the valve spring to compress and the port is fluidly isolated from the pressure equalization conduit in the closed position and is in fluid communication with the pressure equalization conduit in the open position. In the open position, an interior environment of the subsea device is in fluid communication with the environment outside the cap through the equalization valve.

Abstract: A cap for sealing a wellhead assembly of a subterranean well and suspending well assets (e.g., tubing, rods, etc.) therefrom within the well to facilitate production at the well after a period of abandonment. For instance, a decompletion process may be performed on a particular well to be temporarily abandoned which may include disconnecting a pumpjack (e.g., horsehead unit, pumping unit, etc.) from a wellhead of the well, breaking (e.g., disconnecting) the wellhead at the first flange (e.g., closest to ground level) to leave a casing head of the wellhead exposed, and/or the like. Ends of a tubing string and a rod string disposed within the subterranean well may be respectively secured within portions of the disclosed cap. The cap may then be placed and secured over the exposed casing head to limit entry of foreign objects and debris into the well.

Abstract: Apparatus useful for providing a liquid-tight seal around an opening formed in the earth's surface of an underground borehole includes a clamp and at least one platform. The clamp is configured to engage a wall extending around the borehole and the platform is configured to extend outwardly from the clamp over the earth's surface adjacent to the borehole.

Abstract: An integrated wellhead assembly is provided to enable free flow production and artificial lift production from a well without requiring removal and/or reconfiguration of the wellhead assembly. The wellhead assembly includes an upper portion and a lower portion forming an integrated assembly. The upper portion includes a flow tee and at least one set of rams. The lower portion includes a shoulder to receive a hanger. The upper portion may seal the bore of the wellhead assembly and provide full bore access to the bore of the wellhead assembly.

Abstract: A stuffing box isolation apparatus and method for use with a stuffing box at a wellhead. The stuffing apparatus includes an anchor component that secures the apparatus within the stuffing box, when inserted into an open bore of a stuffing box. The apparatus further includes a sealing element that is expandable to sealingly engage an inner surface of the stuffing box. The expansion of the sealing element effectively seals the open bore of the stuffing box, preventing release of wellbore fluids and/or back-flow of the produced fluids.

Abstract: A cap having a stinger adapted to be inserted into a bore of a subsea well element. The stinger includes locking means for locking to a profile in said bore, which locking means include a plurality of locking dogs. The locking dogs exhibit a large inclination face and a small inclination face, and are adapted to be actuated in a radial direction by an actuation sleeve. The small inclination face is divided by a slot, in which slot the large inclination face is arranged. A cam is arranged on the actuation sleeve and is adapted to extend into said slot. Alternatively, the small inclination face is divided by a cam arranged on the locking dog, on which the large inclination face is arranged, which cam is adapted to extend into a slot in the actuation sleeve.

Abstract: A wellhead assembly is provided including a casing and a tubular member mounted over the casing. A flange extends from the tubular member. A generally elongated annular member is provided in the tubular member. The generally elongated annular member has a first end portion above the tubular member and second end portion below the first end portion. A hanger may be suspended within the tubular member. In such case, a seal may be formed between the elongate annular member and the hanger.

Abstract: A system, in certain embodiments, includes a wellhead connector configured to connect with multiple wellheads within a single wellhead conductor. The system may also include a hold down ring configured to be positioned radially around the wellhead connector and to lock the wellhead connector in position axially on top of the multiple wellheads by applying an axially downward force onto the wellhead connector. In addition, the system may include a body lock ring configured to be positioned radially around the multiple wellheads. The system may also include a union ring configured to be positioned radially around both the hold down ring and the body lock ring and to lock the hold down ring and the body lock ring in position adjacent each other axially.

Abstract: A fracturing system including a ring gasket disposed between a fracturing tree and a wellhead component is provided. In one embodiment, the ring gasket includes multiple sealing stages that seal against grooves in the fracturing tree and the wellhead component. The ring gasket may also include one or more recesses between the sealing stages. In some embodiments, the ring gasket has a configuration that reduces gasket setting load and increases flange separation load compared to other gaskets used in fracturing operations. And in some embodiments, the system enables monitoring of gasket sealing integrity, even during fracturing operations. Additional systems, devices, and methods are also disclosed.

Abstract: A wellhead vault for preventing alteration of the wellhead of a water supply. The vault is a heavy bell-shaped structure, formed of concrete, and having a downwardly facing concavity, and the vault placed over, with the concavity around the wellhead. The vaults too heavy to be removed by human lifting. Lifting elements are provided to allow the vault to be installed and removed by heavy construction equipment. The vault has a vent that communicates between the concavity and the outside, allowing air, but not liquid, liquid or solid contaminants, or animals, to pass through.

Abstract: Temporary abandonment caps include a cap body having an opening therethrough, and an inner sleeve that provides access to the wellbore, where the inner sleeve can be accessed through the opening in the cap body when a removable cover is removed. The inner sleeve also includes an injection port and a channel through which fluids for protecting the wellhead can be injected. The temporary abandonment caps can remain in place while performing well operations and ensuring that the sealing surfaces on a wellhead remain protected from corrosion.

Abstract: A cap assembly for sealing the open end of a well casing or other pipe includes a top plate for mounting on the open end of the pipe, a bottom plate spaced apart from the top plate, an upper expansible gasket sandwiched between the top plate and an upper clamping plate, a lower expansible gasket sandwiched between the bottom plate and a lower clamping plate, spacer sleeves extending between the clamping plates, bolts through the bottom plate, both gaskets and clamping plates, the sleeves and the top plate, and nuts on the bolts. When the bolts are tightened on the nuts, the gaskets expand to seal the pipe at spaced apart locations.

Abstract: An integrated wellhead assembly is provided to enable free flow production and artificial lift production from a well without requiring removal and/or reconfiguration of the wellhead assembly. The wellhead assembly includes an upper portion and a lower portion forming an integrated assembly. The upper portion includes a flow tee and at least one set of rams. The lower portion includes a shoulder to receive a hanger. The upper portion may seal the bore of the wellhead assembly and provide full bore access to the bore of the wellhead assembly.

Abstract: A system for sealing a wellhead. The system includes a setting frame, a driver cylinder selectively applying an axial motion, an adaptor attached to the wellhead, and a power mandrel operatively attached to the driver cylinder. The system may also include a setting sleeve attached to the power mandrel, with the setting sleeve having a packer element, wherein the setting sleeve is responsive to a pressure applicator and retractor device so that the packer element is expanded within the master valve. A method of isolating a wellbore is also disclosed.

Abstract: A drive head for a wellhead, the drive head comprising: a rod drive; a pressure chamber; and a rod receiving part connected to the rod drive and enclosed within the pressure chamber. A method comprising: pressurizing a chamber mounted to a wellhead, in which the chamber encloses an upper end of a rod extending from the wellhead; and driving the rod using a rod receiving part enclosed within the chamber.

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: A well head cover includes a polymeric body integrally including a tubular shaped main body portion. A tubular shaped mounting portion extends from the main body portion. A tubular shaped discharge portion is connected to the main body portion and is oppositely directed with respect to the mounting portion. A first discharge tube bore is created through a first end wall provided in the discharge portion. A second end wall is provided in the mounting portion. The second end wall has an end wall portion through which a second discharge tube bore is created. An axial centerline of the second discharge tube bore is coaxially aligned with an axial centerline of the first discharge tube bore. A pipe extending through the well head cover has a diameter adapted to provide a sliding fit with the first and second end walls at the first and second discharge tube bores.

Abstract: A wellhead seal assembly that forms a metal-to-metal seal between inner and outer wellhead members. A metal seal ring has inner and outer legs separated by a slot. An extension of seal ring contacts an upward facing shoulder of the inner wellhead member. An energizing ring with a tapered nose is moved into the slot. The tapered nose has a downward facing stop shoulder that contacts an upper end of inner leg when the energizing ring is in its lower position.

Abstract: An improved hydrotest testing system comprises a safety stop which prevents the testing tools from being blown out of the top of the tubing string. The safety stop is made up into the upward facing box of the tubing joint to be tested, where the stop is positioned between the tool assembly placed within the tubing joint and the no-go head assembly which is located at the surface during the testing operation. Once the safety stop has been made up into upward facing box, the tool assembly is set within the joint to be tested and the joint pressure tested. The safety stop has a generally cylindrical body which has a bore extending through its length, where the bore has a reduced diameter throat which is sized smaller than portions of the downhole testing tool.

Abstract: An integrated wellhead assembly is provided to enable free flow production and artificial lift production from a well without requiring removal and/or reconfiguration of the wellhead assembly. The wellhead assembly includes an upper portion and a lower portion forming an integrated assembly. The upper portion includes a flow tee and at least one set of rams. The lower portion includes a shoulder to receive a hanger. The upper portion may seal the bore of the wellhead assembly and provide full bore access to the bore of the wellhead assembly.

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 uncontrolled flow of fluid from an oil or gas well may be reduced or stopped by injecting a composition including 2-cyanoacrylate ester monomer into the fluid stream. Injection of the monomer results in a rapid, perhaps instantaneous, polymerization of the monomer within the flow stream of the fluid. This polymerization results in formation of a solid plug that reduces or stops the flow of additional fluid from the well.

Abstract: The invention discloses a system and method for controlling a wellbore. The method comprises the steps of: providing a capping stack comprising a number of releasable modules, each module having a size and weight within predetermined limits, wherein said modules include at least one ram type blow out preventer module, and wherein said modules include a connector module for connecting the capping stack to an attachment point of the wellbore; transporting said modules by cargo airplane to a location near the wellbore; interconnecting the modules to provide the capping stack; and connecting the capping stack to the attachment point of the wellbore.

Abstract: A method for determining a position of a fluid discharge in an underwater environment, the method including: collecting data relating to an underwater area through at least two acoustic sensors; filtering and processing the data collected to identify the presence of the discharged fluid and the underwater area involved; forming a single stereoscopic image by combining the plurality of single three-dimensional images; and estimating the position of the fluid discharge on the basis of the stereoscopic image thus obtained.

Abstract: A reinforced wellhead member for use during fracing operations. The wellhead member is preloaded at a flange section by creating compressive stresses via a ring that interacts with a tightening nut on a bolt. The bolt is rigidly attached to an adapter which may also be modified to create stresses on the flange of the wellhead member. The induced stresses counter the tensile stresses experienced by the flange during fracing operations, allowing a standard wellhead member to be utilized.

Abstract: A hydraulic connector for a wellhead hub is provided that includes a piston and a bottom portion configured to move in an axial direction via hydraulic pressure applied to one or more hydraulic ports in the connector. The movement of the piston and the bottom portion moves a ring and a segment of the connector in a radial direction to engage recesses in the wellhead hub. The connector may be unlocked by applying hydraulic pressure to a hydraulic port of the connector. A system and method of operating the connector are also provided.

Abstract: A blowout containment system is permanently positioned on the wellhead. The blowout containment system is relatively inexpensive, is always available and in place, it does not interfere with normal drilling operations, will capture all of the oil and gas emitted by the blowout, does not require special or unique sea surface or underwater apparatus or vessels, does not have any operational requirements that are different than those which drilling crews normally use and are already familiar, and is activated the using actions are similar to those used by drilling crews for well drilling and completion.

Abstract: What is provided is a method and apparatus wherein a rotating and reciprocating swivel of adjustable stroke length and shearable by ram blow out preventers can be detachably connected to an annular blowout preventer thereby separating the lower wellbore from the riser. In one embodiment the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

Abstract: An integrated wellhead assembly is provided to enable free flow production and artificial lift production from a well without requiring removal and/or reconfiguration of the wellhead assembly. The wellhead assembly includes an upper portion and a lower portion forming an integrated assembly. The upper portion includes a flow tee and at least one set of rams. The lower portion includes a shoulder to receive a hanger. The upper portion may seal the bore of the wellhead assembly and provide full bore access to the bore of the wellhead assembly.

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: A wellhead vault for preventing alteration of the wellhead of a water supply. The vault is a heavy bell-shaped structure, formed of concrete, and placed over and around the wellhead. The vaults too heavy to be removed by human lifting. Lifting elements are provided to allow the vault to be installed and removed by heavy construction equipment.

Abstract: Apparatus (10) for restricting a flow of fluid through a bore (14) comprises a bore sealing member (12a) and an actuation assembly for moving the bore sealing member (12a) between first and second configurations. The actuation assembly is configured to isolate first and second end portions (46, 48) of the activation member (12a) from a bore fluid (50). The apparatus (10) provides for moving the bore sealing member (12a) between the first and second configurations without a bore fluid (50) pressure acting on an end portion (46, 48) of the activation member (12a).

Abstract: Systems and methods for the prevention or dissolution of hydrates in an undersea well. One example system includes a submersible isolation bell for capturing effluent being exhausted from the well, and an umbilical. A power cable supplies electric power to the submersible isolation bell, for example for heating of the interior of the submersible isolation bell to prevent or discourage the formation of methane hydrates and the precipitation of other byproducts. Diluents may be supplied to the submersible isolation bell to further discourage the formation of hydrates and precipitation of other byproducts. The diluents may be heated locally at the submersible isolation bell, using electric power supplied by the power cable. A conformable seal may substantially seal the submersible isolation bell to a riser or other structure at the wellhead.

Abstract: A wellhead assembly having a wellhead housing, a casing hanger set within the wellhead housing, and sealing areas provided on opposing surfaces of the wellhead housing and casing hanger. The sealing areas circumscribe an axis of the wellhead assembly along respective axial distances on the wellhead housing and casing hanger. A seal is included with the wellhead assembly that has inner and outer legs that respectively engage the sealing areas and form sealing surfaces against the sealing areas. The axial distances of the sealing areas exceeds the length of the inner and outer legs, so that an original seal can be removed and replaced by a secondary seal, wherein the secondary seal engages sealing areas different from the sealing areas engaged by the original seal.

Abstract: The lockdown mechanism (10) and running tool (50) are provided for securing the casing hanger (12, 13) within the wellhead (14) and sealing the annulus between the casing and the wellhead. The lockdown ring (20) fixes the lockdown sleeve (40) to a wellhead in response to a lockdown piston (22). A first seal (24) energized by the running tool seals between the lockdown sleeve and the wellhead. Ball seat (30) is axially movable within the running tool, and a second seal also energized by the running tool (32) seals between the lockdown sleeve and the casing hanger.

Abstract: A wellhead connection to casing is formed from an upper head housing, a slip bowl housing and slip segments. First compression spring extending vertically between slip segment and the a slip bowl housing, and second compression springs extending generally horizontally between adjacent slip segments maintain the slip segments out of gripping engagement with the casing until the slip bowl housing and the upper head housing are fully connected together. On disconnecting the housings, the first compression springs push the slip segments apart from the slip bowl housing, and the second compression springs push the slip segments radially apart from the casing.

Abstract: A removable orifice plate device includes a body having an un-threaded portion which includes a groove. An orifice plate receiving slot bisects the groove and extends partially through a body diameter. An orifice plate having an orifice slides into the orifice plate receiving slot with an orifice central axis co-axially aligned with a longitudinal axis of the body at an orifice plate installed position in the orifice plate receiving slot. A tab integrally extends from the orifice plate and is oriented perpendicular to a body of the orifice plate. The tab includes an indicator symbol, the indicator symbol visually identifying a predetermined size of the orifice. A transparent indicator sleeve is slidably disposed on a body outer surface and is axially slidable between a first position covering the groove to a second position exposing the groove. The indicator symbol is visible through the indicator sleeve in the first position.

Abstract: A hydraulic connector for a wellhead hub is provided that includes a piston and a bottom portion configured to move in an axial direction via hydraulic pressure applied to one or more hydraulic ports in the connector. The movement of the piston and the bottom portion moves a ring and a segment of the connector in a radial direction to engage recesses in the wellhead hub. The connector may be unlocked by applying hydraulic pressure to a hydraulic port of the connector. A system and method of operating the connector are also provided.

Abstract: A modular wellhead system having the capability for single or dual annulus via interchangeable heads, a unique capping system, and other features. A unique wellhead manual positive lock system incorporating an energizable inner bite ring for engaging the casing tubing, a compressible slip hanger for the tubing, as well as a hydraulic jack for lifting the tubing from the well to reintroduce tension are provided, the system being particularly suitable for use in conjunction with repair or low pressure plug and abandon (P&A) operations. Components of the system are designed for assembly via locking pins for diver friendly operation, While the present system is designed principally for use in subsea environments, the system can likewise be utilized on land or platforms.

Abstract: Sealing mechanisms are provided. In one embodiment, a system includes a connector configured to couple one or more flow-control valves to equipment installed at a well and an isolation sleeve configured to be retained by the connector. The isolation sleeve may include a seal and a hydraulically actuated piston disposed adjacent one another about a body of the isolation sleeve such that actuation of the piston engages the seal. The isolation sleeve may also include a mechanically driven actuator ring, where the actuator ring energizes a seal against the bore of a tubing hanger. Additional systems, devices, and methods are also disclosed.

Abstract: A power slip extends a joint from tubing disposed in casing at a well so that a casing head can install on the casing and the tubing can be packed-off from the casing. The joint attaches to an inner sleeve having collet members that fit onto the inner tubing so that the joint extends thereabove. An outer sleeve and interlocking collet assemble together and install onto the inner sleeve. The collet threads onto the inner sleeve and forces the outer sleeve downward onto the inner sleeve. Being forced, the outer sleeve causes the collet members to engage around the inner tubing. The casing head then installs on the casing with the joint extending up through the head's bowl. An H-plate installs in the open bowl around the extended joint, and another pack-off installs on the joint to pack it off from a spool attaching to the casing head.

Abstract: Disclosed is an apparatus for completion of a well. The apparatus includes a tubular configured to be disposed in a wellbore penetrating the earth where an annulus region is defined between an exterior surface of the tubular and a wall of the wellbore. The apparatus further includes a plurality of sensors disposed in the annulus region and configured to sense hydrocarbons during cementing of the tubular to the wall of the wellbore. A receiver is disposed remote from the wellbore and configured to receive measurement data from the plurality of sensors and to provide an indication if hydrocarbons are sensed in the annulus region.

Abstract: Several, preferably three, deflection elements are placed and fixed around the wellhead, preferably in equal circumferential distances around the wellhead. For each deflection element a guiding cable is lowered with its head end from one or several, preferably three workspaces in the direction of the wellhead. Each guiding cable is looped with its head end through the corresponding deflection element, wherein each deflection element forms a point of reversal. Each guiding cable is pulled back with its head end side to the corresponding workspace while in return additional guiding cable is supplied and passed through the corresponding deflection element. A sealing element which is fastened to each guiding cable is lowered in the direction of the wellhead by pulling the guiding cables at their head end sides upwards and, in return, supplying the guiding cables in the direction of the wellhead on the lowering side.

Abstract: A covering that has a means for support, a means for abutment to a wall, and a means for retaining a sensing element. The covering includes a body portion and a perimeter portion with a plurality of radially extending fins. Fins with or without boss are useful for abutment to a wall or surface. One or more means for retaining positioned in the interior of the body, are useful for fixedly positioning or holding a sensing element. The covering may be position on or into a hole and optionally includes additional elements for function and use, such as reinforcing members on the radially extending fins, a central hub, and a spool position around the hub.

Abstract: A wellhead connection including first and second housings with the first housing partly within the second housing to form an annulus. The housings form a seal to a cylindrical inner bore when connected together. The first housing has a circumferential groove formed in its outer periphery. A radially expandable and contractable latch ring formed from latch ring segments is located in the annulus adjacent the circumferential groove. Radial actuators extend through the second housing to the latch ring segments to move the latch ring segments between a contracted position with the latch ring in contact with the circumferential groove, and an expanded position, with the latch ring out of contact with the circumferential groove. The upper and lower housings are adapted to lock the latch ring in the contracted position by applying a downward force on the latch rings, or by tightening the bottom connector to a wellhead member.