Abstract: A technique for subsea operations utilizes a surface vessel to perform the installation and retrieval of submersible pumps or other tools with respect to a subsea well. A submersible pump is conveyed from a surface vessel to a subsea installation which is used to temporarily secure the submersible pump. Subsequently, the surface vessel is again used in cooperation with a conveyance to deliver the submersible pump to a desired location in a wellbore beneath the subsea installation.

Abstract: The present invention discloses apparatus and methods for a lightweight subsea intervention package that may be installed using vessels with a smaller lifting capacity than semi-submersible platforms so that the subsea intervention package can be transported, installed, and removed from a subsea well in less time and with less cost. In one embodiment, the present invention comprises a lower riser package for controlling the subsea well which utilizes two hydraulically activated gate valves. An emergency disconnect package is secured to the lower riser package utilizing a disconnect mechanism. The emergency disconnect package is operable to seal the bottom of a riser if the disconnect mechanism is activated to thereby minimize environmental leakage of fluid from the riser.

Abstract: A technique enables protection of subsea wells. The technique employs a subsea test tree and associated control system to ensure control over the well in a variety of situations. The subsea test tree may be formed with an upper portion releasably coupled to a lower portion. The upper portion employs at least one upper shut-off valve, and the lower portion employs at least one lower shut-off valve to protect against unwanted release of fluids from either above or below the subsea test tree. The subsea test tree also is coupled with the control system in a manner which allows control to be exercised over the at least one upper shut-often valve and the at least one lower shut-off valve.

Abstract: A wellhead assembly for use subsea includes a high pressure housing landed within a low pressure housing. The low pressure housing is an annular member that mounts into the sea floor and having an inner surface engaging the high pressure housing along a loading interface. Upper and lower sockets are formed along axially spaced apart portions of the outer surface of the high pressure housing. As the high pressure housing inserts into the low pressure housing, the high pressure housing sockets engage corresponding sockets formed along axially spaced apart sockets on portions of the inner surface of the low pressure housing. The sockets each have cylindrically shaped outer surfaces, and when engaged with one another define the loading interface. The sockets are strategically located on the upper and lower portions of the housings to maximize their distance apart.

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: 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 pressure mitigating device is used to reduce pressure in a void within a wellhead housing. In one embodiment, the pressure mitigating device includes two plates that define a void between them. Increased pressure in the wellhead housing causes the plates to elastically displace towards each other. The plates contact each other, limiting the displacement prior to plastic deformation.

Abstract: A production assembly and method for controlling production from production tubing supported by a tubing hanger in a well including a wellhead. The assembly includes a function spool engaged with the wellhead and a tree engaged with the function spool. The tubing hanger is landable in the tree bore such that the production tubing is supported in the well by the tree. A function mandrel separate from the tubing hanger is engaged with the production tubing and positionable inside the function spool bore. The function mandrel includes a passage connected to a line extending into the well that is connectable with a port in the function spool such that communication with a downhole component through the line is allowable from outside the function spool.

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: The present invention relates to a fluid circulation system for circulating fluid in a subsea cavity, the cavity being filled with a first fluid and having first and second end ports. The system comprises a container (26) containing a second fluid, fluid lines (21, 27) extending from the container to the first and second end ports of the cavity, respectively, and a pump (22) for exchanging the second fluid provided in the container (26) and the first fluid provided in the subsea cavity (10). The invention also relates to a method for circulating fluid in a subsea cavity.

Abstract: An apparatus to allow backup or alternate fluid flow routes around malfunctioning BOP control components using a remotely installed removable hydraulic hose connection. The backup fluid flow route sends pressure-regulated hydraulic fluid to a BOP operation via an isolation valve rigidly attached to the BOP, then to a hose connected to an intervention panel on the BOP and finally through a valve that isolates the primary flow route and establishes a secondary flow route to allow continued operation. To increase reliability, the backup components route from a spare BOP function and are rigidly fixed to the BOP.

Abstract: Apparatus for the insertion of a pack-off into a recess in a bore of a wellhead body includes an activating sleeve which has a portion disposed for engagement with the pack-off for the movement of the pack-off into the recess and body portions shaped for location on a datum member within the bore. The activating sleeve includes a plurality of apertures circumferentially spaced about the activating sleeve. A running tool which is adapted to move the activating sleeve into engagement with the pack-off carries spring-loaded dogs each disposed in one of the apertures. Each of a plurality of releasing pins is positioned such that it enters a respective one of the apertures when the activating sleeve has caused the pack-off to be located in the recess. The entry of the pins into the apertures causes depression of the dogs out of the apertures and allows the consequent release of the activating sleeve from the running tool.

Abstract: A retrievable bridge is provided which mounts to the top of a subsea tree to provide fluid communication between the production line of the subsea tree and a production flowline. The retrievable bridge mounts to the top of the subsea tree and preferably connects to a vertically oriented pipe of the production flowline. The retrievable bridge can be utilized to carry wear items such as chokes, subsea control modules, and flow meters which may require maintenance more often than other components of the subsea tree. By mounting these items along the flow passageway in the retrievable bridge the components are securely mounted and still available for maintenance/replacement without the need to remove the entire tree. In one embodiment, Intervention into the well is available without removing the retrievable bridge.

Abstract: A cap system for subsea equipment that can be employed on various subsea equipment including but not limited to a vertical monobore tree, a horizontal tree, a wellhead and a tubing head spool. The cap system includes a cap assembly that has the flexibility of installation and retrieval for open water as well as a through a riser with a running tool. The cap assembly also does not require any orientation during installation. The cap system includes a debris cap assembly installable in engagement with the cap assembly. The debris cap assembly interfacing with the cap assembly provides the ability to inject and bleed fluids through a main bore and an annulus bore of the subsea tree independently and without removal of the debris cap assembly and cap assembly.

Abstract: A blow out preventer comprises a valve casing assembly, a tubing cutter, a hydraulic cylinder and piston, and a linkage assembly. The valve casing assembly has a first port and a second port. The ports are in axial alignment along a longitudinal axis extending between the ports. The well tubing is run through the ports and transversely through the tubing cutter. The tubing cutter is rotatably positioned in the casing assembly and is rotatable from a first position to a second position. The tubing cutter has an axis of rotation which is transverse to the longitudinal axis of the valve casing assembly. The piston is annularly shaped and moves parallel to the longitudinal axis of the valve casing. Linkage between the piston and the tubing cutter converts the axial movement of the piston into rotational movement of the tubing cutter to shear the tubing when needed. When the tubing has been sheared, a seal is formed between a face of the tubing cutter and a valve seat in the valve casing assembly.

Abstract: A subsea well production system for a well including a subsea wellhead. The system includes a multi-section production tree that includes a landing section engageable with the subsea wellhead and including a landing section bore. The tree also includes a valve section separate from and engageable with the landing section, the valve section including a lateral production port extending through a valve section wall and in communication with a valve section bore. A production tubing supported by a tubing hanger is installed and supported in the landing section bore such that the tubing hanger extends into the valve section bore. The tubing hanger and production tubing are retrievable through the section bores without disengaging the valve section from the landing section. The valve section is also disengageable from the landing section with the tubing hanger remaining in the landing section.

Abstract: A subsea wellhead assembly includes a housing with a bore. A hanger is lowered into the housing, the hanger having at least one centralizing finger with a hook for engaging a corresponding hook an activation ring carried by the hanger via a shear pin. A load ring is carried on the hanger and supported initially within a recess formed on the exterior of the hanger. At the correct depth within the housing, coinciding with a shoulder on the inner diameter of the housing, the pin is sheared under the weight of the casing string and the hooks disengage to allow the load ring on the hanger to slide outward and create a path for the casing load to be transferred from the hanger to the hanger load ring, to a housing load ring, and ultimately the housing.

Abstract: A subsea production system for a well including a subsea production tree, a tubing hanger, and a production tubing extending into the well and supported by the tubing hanger. A downhole equipment suspension system includes a suspension head supported directly or indirectly by the production tree above and separately from the tubing hanger. The suspension system also includes downhole equipment inside the production tubing below the tubing hanger and a suspension line extending through the tubing hanger vertical production bore and the production tree vertical bore. The suspension line suspends the downhole equipment from the suspension head.

Abstract: Subsea well assembly having a Xmas tree (107, 207) and wellhead (103). From a tubing hanger (113) a tubing extends into the well. A part of a production flow passage extends vertically from the tubing hanger (113) in a vertical bore (111) of the Xmas tree. A fail close production master valve (PMV) (117) is arranged in the production flow passage. The tubing hanger (113) is arranged below the Xmas tree (107), such as in the wellhead (103). The Xmas tree (107) exhibits a branch (115) that deviates from the vertical bore (111), which branch constitutes part of the production flow passage. The fail close type production master valve (PMV) (117) is arranged in the branch (115).

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: Systems can be configured to move a ram block in a blowout preventer. The system includes: a first bank of accumulators configured to provide a first pressure to move the ram block; a second bank of accumulators configured to provide a second pressure to move the ram block, wherein the second pressure is greater than the first pressure; and a controller configured to sequentially control the first bank of accumulators to apply pressure to move the ram block and to then control the second bank of accumulators to move the ram block after the first bank of accumulators has moved the ram block a first distance.

Abstract: A bridging hanger with an expandable anchoring mechanism lands on a casing hanger in a subsea wellhead and actuates to anchor to the casing hanger. The anchoring mechanism includes a tubular main body, and a tubular sealing sleeve. The tubular sealing sleeve is coaxial with and mounted on an exterior diameter portion of the tubular main body. The body is moveable from an upper run-in position to a lower set position relative to the sealing sleeve. The anchoring mechanism also includes a first and second locking ring, both carried by the sealing sleeve. The first locking ring engages a profile within an interior of the casing hanger in response to movement of the main body from the run-in to the set position. The second locking ring locks the tubular main body in the set position in response to movement of the main body from the run-in to the set position.

Abstract: Methods for deploying a subsea blowout preventer stack system comprising a lower marine riser package, a blowout preventer stack with a first ram blowout preventer, and an additional blowout preventer package releasably coupled to the blowout preventer stack and comprising a second ram blowout preventer. The subsea blowout preventer stack assembly can be deployed by coupling a drilling riser to the lower marine riser package that is releasably connected to the blowout preventer stack. The lower marine riser package and blowout preventer stack are then toward a subsea wellhead and then landed on the additional blowout preventer package that is coupled to the subsea wellhead.

Abstract: A wellhead system comprising a seal with a restraining member adapted to cooperate with a housing to restrict axial movement of the seal. The seal is adapted to form a seal between the housing, such as a wellhead, and a tubular member, such as a casing hanger. The seal has a latch ring that is expanded outward as the seal is installed within the wellhead. Axial movement of the seal is restricted by engagement between the expanded latch ring and the inner profile of the housing. The seal and housing may be adapted so that a portion of the seal is received by a recess in the inner profile of the housing.

Abstract: A modular assembly for a wellhead has a housing and a plurality of modular cartridges. The housing connects with a studded or flanged connection to the wellhead, which can have a tubing adapter, casing hanger, etc. The modular cartridges can interchangeably stack in the housing's internal pocket so that the bores of the stacked cartridges configure the through-bore of the assembly communicating the wellhead with external components, such as flow lines, capillary lines, etc. The modular cartridges include a spacer cartridge, a hanger cartridge, a valve cartridge, and a cross cartridge. The spacer cartridge can be used to space other cartridges in the internal pocket, and the hanger cartridge can be used to support capillary strings and/or velocity strings in the wellhead. The valve cartridges have valve elements that can be opened and closed by bonnets that affix externally to the housing.

Abstract: A tubing hanger body made from Non-CRA steel coupled to production tubing made from CRA material. The coupling includes pin threads at the top end of the production tubing which are arranged to be screwed into box threads of the tubing hanger body. A seal sub having metal-to-metal and/or elastomeric seals engages the top end of the production tubing and protects the tubing hanger body from contact with production fluid flowing from the production tubing below to a Christmas tree tubing above. The invention includes a method of repairing of an existing tubing hanger body where its through bore has been damaged. This allows the through bore to be over machined and a CRA sleeve installed to replace tubing threads and body material.

Abstract: A gate valve assembly (100) for use in subsea workover systems is disclosed. In an embodiment, the gate valve assembly (100) includes a valve block (102). The valve block (102) includes a cutting gate (204) disposed in a valve cavity (206) such that the cutting gate (204) can engage in a reciprocating motion in the valve cavity (206) between an “open” position and a “closed” position. The reciprocating motion of the cutting gate (204) results in a cutting operation of a tubing conveyed string passing through the gate valve assembly (100). The gate valve assembly (100) further includes a slug pit (202) formed in the valve block (102) alongside the valve cavity (206). The slug pit (202) defines an opening which can contain one or more cuttings from tubing conveyed springs resulting from the cutting operation. The reciprocating motion of the cutting gate (204) transports one or more cuttings of the tubing conveyed string to the slug pit (202).

Abstract: A method of evacuating hydrocarbons from a plurality of nested tubulars of a well pipe that extends from an underwater well tree includes an initial step of attaching a fluid transmission line to the underwater well tree, the fluid transmission line having one end portion forming the attachment to the tree and the other end portion attached to a pump that forces fluid under pressure to the tree and attached nested tubulars. Openings are formed through one or more tubulars of the nested tubulars at a selected location. A specially configured fitting is attached to the tubulars. The fitting seals the openings. The fitting has an expandable seal that is expandable responsive to rotation of a rotating member that rotates upon a saddle, pulling a tapered mandrel against the seal. The saddle surrounds the mandrel and bears against an outer tubular of the nested tubulars. The fitting mandrel has a bore. Hydrocarbons escape from the tubulars via the mandrel bore.

Abstract: Wellhead-based systems, apparatus, and methods for controlling a well are provided. During a failure of an emergency system such as a blowout provider, a wellhead based emergency control apparatus according to an embodiment of the invention can be employed to control the well. A casing strings compression assembly can radially compress each of the casing strings and/or drilling pipe extending through the wellhead housing to restrict or stop well fluid passage. A casing strings penetrator of an emergency well fluid diversion assembly can also or alternatively be employed to form an aperture in the casing strings. A diverter, integral with or connected to the penetrator, is extended through an aperture in a side of the wellhead housing and one or more of the apertures cut by the penetrator to divert well fluid from within the wellhead housing through a passageway in the diverter and to an external conduit.

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: 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: 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: Disclosed herein is a subsea well assembly; wherein in an example embodiment the subsea well assembly includes an umbilical attached to a power source. The power source can be on a platform. Also included is a connector for connecting the umbilical to a receptacle included with the subsea well assembly and a subsea control module delivering power and control signals to the subsea well assembly. An impressed current protection module is integrated in the subsea control module that receives power from the umbilical.

Abstract: An apparatus for controlling the flow of a first fluid stream within a bulk rotating fluid stream is disclosed, the apparatus comprising a fluid flow region having a longitudinal axis, within which a rotating flow of fluid may be established; a flow guide having a convex outer surface disposed centrally within the fluid flow region, the convex outer surface of the flow guide extending parallel to the longitudinal axis of the fluid flow region, the convex surface being shaped to induce a spiral coanda effect in the flow of the first fluid stream over the flow guide.

Abstract: An embodiment of a method for limiting the probability of failure on demand of a subsea test tree (“SSTT”) includes the steps of providing a safety shut-in system for actuating a safety valve of the SSTT, the safety shut-in system including a surface control station positioned above a water surface connected via an umbilical to a subsea control system positioned below the water surface to actuate the safety valve; and diagnostically testing the safety shut-in system without actuating the safety valve.

Abstract: A subsea completion for a well is presented that includes a tubing spool, a tubing hanger, a fluid coupling, an electrical coupling, a control system, a valve, and a production tree. The tubing spool includes a central bore, a side wall, and a fluid supply passage extending through the tubing spool. An electrical supply passage can also extend through the side wall of the tubing spool. The tubing hanger includes a fluid control passage. The tubing hanger can also include an electrical control passage. The control system includes a fluid control conduit to provide fluid to the tubing spool fluid supply passage from outside the tubing spool. The valve is connectable to the outside of the tubing spool to control fluid flow between the control system fluid conduit and the tubing spool fluid supply passage.

Abstract: A running tool sets and pressure tests a bridging hanger and a packoff in a single trip. The running tool has a stem, an inner body, and a piston. The inner body is connected to the stem so that rotation of the stem relative to the inner body will cause the stem to move longitudinally. The piston is connected to the stem so that the stem and piston rotate and move longitudinally in unison. A piston engagement element is housed in the inner body and is adapted to engage the piston when the bridging hanger is set to prevent premature setting of the packoff. The piston engagement element can be disengaged once the bridging hanger is set, thereby allowing the piston to set the packoff.

Abstract: A subsea cutting device for a subsea blow-out preventer or wellhead comprises a tubular body having an axial throughbore, and configured to be fitted to a casing string, the cutting device further comprising a shearing mechanism in the form of a radial cutting system rotatably mounted within a pressure-containing housing, and comprising a plurality of movable cutters arranged around the throughbore and configured for deployment during rotation successively inwards. The cutting device is useful in a subsea shut off device which is latched to a template at surface and run to the sea floor on a casing string which is drilled into place and converted into a riser on a single trip. For the event when emergency disconnection is required, the device may be used to cut the casing and seal in the well. The system then allows a conventional subsea reconnection of the riser.

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 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 mechanism for clamping first and second stabplates together comprises a pivoted cam member and clamping means for co-operating with the cam member. The mechanism is such that the cam member is displaceable between a first position in which, in co-operation with the clamping means, it clamps the stabplates together and a second position in which it has rotated to be between the stabplates with the stabplates separate from each other.

Abstract: A remote operated vehicle (ROV) interface has a retrievable portion and a permanent portion. The permanent portion includes a housing that has a cavity that secures to a drive stem of the subsea well device. The housing has a pod cavity on an opposite end that receives a pod body, which is part of the retrievable portion. The pod body is secured by spring-biased retainer within the pod cavity. The pod body has a cylindrical receptacle that receives a drive pin, which forms another part of the retrievable portion. The drive pin and the cylindrical receptacle are engaged for rotation by a shear element. The pod body has an ROV retrieval profile that is accessible by an ROV. In the event the shear element shears due to excessive torque, an ROV retrieval tool engages the pod body and retrieves the pod body along with the drive pin.

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 wellhead is provided. In one embodiment, the wellhead includes a plug for sealing a side passage of the wellhead. The plug may include an outer member, an inner member extending through the outer member and coupled to the outer member with at least one degree of freedom of movement relative to the outer member, and a moveable seal disposed around the outer member. In some embodiments, the moveable seal is configured to seal against the side passage in response to being moved on the outer member by the inner member.

Abstract: A subsea wellhead a generally cylindrical body including a lower extension for forming an annular space for a cement column between the lower extension and an outer conductor. The extension carries a multiplicity of interfitting rings forming a sleeve which facilitates flexure of the extension in the presence of the cement column. Each ring may comprise an inner flange for disposition adjacent the outside of the extension and an outer flange for fitment over the inner flange of an adjacent ring. The outer flange may have a radial through-bore.

Abstract: An outer tubular wellhead member having wickers formed in a bore of the outer tubular wellhead member that vary in axial position and methods to assemble a subsea wellhead including the same is disclosed. The plurality of circumferentially extending wickers are formed in sealing profiles of the wellhead member. Each wicker varies axially in position around the circumference of the bore so that when a seal member engages each wicker, the wicker deforms the surface of the annular seal to form circumferential sealing bands at each wicker from an upper end of the sealing profile to a lower end of the sealing profile, upper portions of each wicker deforming the surface of the annular seal before lower portions of the same wicker so that fluid between adjacent wickers flows from the higher axial location of the wicker to the lower axial location of the wicker to limit hydraulic lock.

Abstract: A production assembly and method for controlling production from production tubing supported by a tubing hanger in a well including a wellhead. The assembly includes a function spool engaged with the wellhead and a tree engaged with the function spool. The tubing hanger is landable in the tree bore such that the production tubing is supported in the well by the tree. A function mandrel separate from the tubing hanger is engaged with the production tubing and positionable inside the function spool bore. The function mandrel includes a passage connected to a line extending into the well that is connectable with a port in the function spool such that communication with a downhole component through the line is allowable from outside the function spool.

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 control and supply unit for an actuating device of a choke, a valve, a blow-out preventer or some other device applied in the field of oil and natural gas production. The control and supply unit includes an auxiliary power supply that is rechargeable and a connecting means to exchange data or supply a voltage. The unit is implemented separately from the actuating device and the connecting means is connected via a cable connection to a separate plug connection module arranged on the actuating device.

Abstract: A completion system for a subsea well includes a tree having a generally cylindrical wall forming an internal bore therethrough and a production port extending laterally through the wall in communication with the internal bore. The internal wall has a landing arranged to support a tubing hanger having seals for sealing the production port between the tubing hanger and the internal wall, the production port being arranged to communicate with a lateral production fluid outlet port in the tubing hanger. A workover port extends laterally from an opening in the internal wall below the production port and the production port seals and a tubing annulus seal sealing the workover port from the tubing annulus. A tubing annulus port extends from an opening in the tree below the tubing annulus seal and the tubing annulus port and workover port being arranged to be in fluid communication externally of the internal bore.