Abstract: A subsea wellhead assembly includes a housing with a bore. A hanger is lowered into the housing, the hanger having at least one downward facing load shoulder. An expandable load ring is carried on the hanger. When casing weight is applied to the hanger, the weight energizes the load ring, causing it to expand and thereby increase the contact area between a load shoulder on the load ring and a load shoulder on the housing. The shoulders create a path for the load to be transferred to the housing. The increase in contact area increases the load carrying capacity of the hanger. The load ring expansion is limited to elastic expansion to allow it to return to a retracted position when the casing weight is removed.

Abstract: Latch position indicator systems remotely determine whether a latch assembly is latched or unlatched. The latch assembly may be a single latch assembly or a dual latch assembly. An oilfield device may be positioned with the latch assembly. Non-contact (position), contact (on/off and/or position) and hydraulic (flowmeter), both direct and indirect, embodiments include fluid measurement systems, an electrical switch system, a mechanical valve system, and proximity sensor systems.

Abstract: A subsea wellhead assembly includes a production casing hanger defining a series of passageways from an annulus between a production casing string and an outer casing to a region that can communicate, for example, by way of an isolation sleeve, with a production tree. The passageways extend to the interior of the casing hanger. A positionally adjustable sleeve fits within the casing hanger and carries exterior seals that are disposed so that for a first position of the adjustable sleeve within the casing hanger, fluid passage through the series of passageways is blocked, and for a second position of the sleeve within the casing hanger, the fluid passage is allowed. The adjustable sleeve can be operated by a simple tool through the production tree.

Abstract: A wellbore sealing assembly can include a sealing ring, an energizing ring, and a multifunctional key for engaging the sealing ring and the energizing ring. The multifunctional key can have a key body, a guide member, and a retainer stud. The key body can be located in an aperture in a sidewall of the sealing ring and the guide member and retainer stud can protrude through the sidewall into a guide slot and recess of the energizing ring. Downward force on the energizing ring can cause the retainer stud to shear away while the guide member travels in the guide slot to prevent rotation of the energizing ring relative to the sealing ring. The guide member can also aid in complete seal retrieval by locking against the bottom of the key-way slot in the energizing ring.

Abstract: A subsea wellhead assembly includes a wellhead body which disposed to support an isolation sleeve for a production tree and to support below the isolation sleeve a production casing hanger for a production casing string. The body also supports a second casing string outside the production casing string whereby to form an annulus between the casing strings. The body includes a passageway which is in communication with the annulus near a lower end of the body and extends upwardly within the wall of the body towards the upper end of the body. A valve is accommodated in the upper part of the body and provides controlled communication between the passageway and a port which can be coupled to the isolation sleeve. The valve is controllable from a production tree in particular is moveable between an open position and a closed position in response to fluid pressure applied to the valve from a production tree by way of the isolation sleeve.

Abstract: A wellhead assembly made up of a wellhead housing, a production tree mounted on the wellhead housing, tubing suspended into a wellbore from within the wellhead housing, and an annulus between the tubing and the wellhead housing. A shuttle valve is provided within a tubing hanger that supports the tubing from within the wellhead housing. An accumulator is disposed in the annulus that is in fluid communication with a closed position port on the shuttle valve. Pressure is maintained in the accumulator for closing the shuttle valve when a force for opening the valve is removed.

Abstract: A casing hanger seal assembly is lowered into a pocket between a casing hanger and a wellhead housing while in a run-in position. The seal assembly has a metal-to-metal upper seal ring and an elastomeric and metal lower seal ring carried by and below the upper seal ring. The upper and lower seal rings are movable from a run-in position to a set position sealing between the sidewalls of the casing hanger and the wellhead housing by applying a downward force. The downward force required to move the lower seal ring to the set position is less than the downward force required to move the upper seal ring to the set position. A downward force applied to the upper seal ring after the lower seal ring has landed in the pocket transfers to the lower seal ring to cause the lower seal ring to move to the set position before the upper seal ring moves to the set position.

Abstract: In some embodiments, apparatus useful for providing tubing into an underwater well includes at least one surface injector configured to control movement of the tubing into and out of the well and at least one underwater injector configured to apply pushing and pulling forces to the tubing.

Abstract: A method of running a down hole rotary pump using a top drive, sucker rod or any drive shaft from surface. A first step involves providing a gear box having an input end and an output end. The gear box is being capable of receiving an input of a first speed at the input end and producing an output of a second speed which is one of either faster or slower than of the first speed at the output end. A second step involves positioning the gear box down hole with the input end coupled to a remote lower end of a sucker rod and the output end coupled to a rotary activated pump. A third step involves applying a driving force to the sucker rod to rotate the sucker rod at the first speed, with the rotational force being transmitted to the rotary activated pump through the gear box which rotates the rotary activated pump at the second speed.

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: The method for subsea well intervention includes creating a lubricator section within the production tubing of the well. The lubricator section can then be flushed of hydrocarbons facilitating further well intervention from the open water. An intervention device that facilitates flushing production tubing that has equipment, such as electric submersible pumps, is deployed in the wellhead, for example in the valve tree.

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 walls separated by a slot. An elastomeric seal is located below the seal ring and has a bottom portion that contacts an upward facing shoulder of a hanger. An energizing ring with a tapered nose is moved into the slot. The tapered nose has a compound angle that determines how much the nose travels into the slot when a force is applied to the energizing ring. Once the elastomeric seal is compressed to a desired level, the load on the energizing ring has increased to the point that the tapered nose of the energizing ring will further enters the slot and force the outer and inner walls of the metal seal into sealing engagement with the inner and outer wellhead members.

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 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 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: 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: 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 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: Apparatus for improving the safety and recovery of wells to be installed in oil wells comprising a Deep Set Well Head (DSWH), a Casing Receptacle (1), a Deep Set Tubing Hanger (DSTH) (2), Sub-Surface Safety Valves (SSSVs) (12) (13) with one or two independent Control Lines and Connection elements between the DSTH and well head.

Abstract: The present invention provides a wellhead securement arrangement including a first inner casing string 32 which is held in axial loading and a second inner casing string 56 which is also held in axial loading. Both of the first and second inner casing strings 32, 56 are releasably clamped such that the casing strings 32, 56 cannot move in an upwards or a downwards longitudinal direction. Prior to being clamped in such a position, the wellhead securement arrangement provides first retaining means to retain the first and second casing strings in cementing position whereby “cement returns” are able to flow around the respective hangers 36, 58 and upward through a casing towards the surface. Once cemented, the upper hangers 36, 58 of the respective inner casing strings 32, 56 are moved upwardly where the hanger 36, 58 is then clamped in position to maintain the respective inner casing string 32, 56 under an axial load whilst being prevented from moving either upwardly or downwardly.

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 high capacity single trip lockdown bushing and a method to operate the same is disclosed. The lockdown bushing includes a tubular body that carries a locking ring and an energizing ring about an upper portion of the tubular body. The energizing ring includes a cam portion interposed between the locking ring and the tubular body so that the cam portion and the locking ring overlap along mating cam surfaces in an unset position. A running tool carries the lockdown bushing to land on a casing hanger. The running tool is actuated to drive the energizing ring downward so that the mating cam surfaces interact to move the locking ring radially outward into engagement with wickers formed in a wellhead.

Abstract: A clamp for securing about annular casing via a centrally oriented aperture having a radius includes at least one aperture for grasping a longitudinally extending accessory disposed about the radius of the centrally oriented aperture and at least one fastening member for securing the longitudinally extending accessory about the clamp. At least one fastening member and at least one aperture act to secure a longitudinally extending accessory relative to the annular casing.

Abstract: An apparatus for, and method of, lowering items from a drilling rig to a well located below it through the use of a landing string comprised of drill pipe having an enlarged diameter section with a shoulder, in combination with upper and lower holders having wedge members with shoulders that engage and support the drill pipe at the shoulder of the enlarged diameter section, the shoulder of the drill pipe and the shoulders of the wedge members being rotatable with respect to each other.

Abstract: A floating structure includes a riser support system. The riser support system includes multiple carts, each suitable for moveably connecting a risers to the riser support system. A cart includes a support frame and one or more riser tensioners for connecting the support frame to a riser. Each cart is designed for being supported by a cart support structure in a production dock and in a drilling dock, and for being transferred by a crane between the production dock and the drilling dock. Thus, the riser support system enables transferring risers and their riser tensioners within the moonpool from a production dock to a drilling dock without the need of disconnecting and/or reconnecting the risers to extra riser tensioners for support in the drilling dock or during transport.

Abstract: A wear bushing (10) and a running tool (32) are provided for a subsea wellhead assembly including a wellhead housing and a casing hanger. The wear bushing is landed on the casing hanger, and a connector (16) axially connects the wear bushing and the wellhead housing. The running tool is actuated to connect the wear bushing, such that at least a portion of the connector is received within a corresponding recess in an interior wall of the wellhead housing. A bushing/casing hanger latch (18) axially connects the wear bushing and the casing hanger.

Abstract: A subsea wellhead assembly having a tubing hanger set in a tubing hanger spool and a ring with axial passages set in an upper end of the tubing hanger. The wellhead assembly includes a production tree that lands on the tubing hanger spool. Tubing extends from the axial passages in the ring through axial bores provided in a sidewall of the tubing hanger. When landed, a lower end of the production tree engages an upper surface of the ring causing the ring to rotate and align its axial passages with axial passages in the production tree. The respective lower and upper surfaces of the tree and ring are strategically castellated to orient the passages.

Abstract: A hang-off assembly for supporting a riser string from an off-shore drilling rig. The hang-off assembly includes a housing with a passage through the housing and an open section allowing access to the entire length of the passage from outside the housing. The assembly also includes a gate member movable relative to the housing from an open position to a closed position, the gate member preventing access to the passage through the open section when in the closed position. A motor moves the gate member between the open and closed positions. An adapter attachable to the riser string includes a profile landable in the housing to support the riser string when connected to the adapter.

Abstract: An embodiment of a running tool for setting and testing a packoff seal of a well pipe hanger has an elongated stem having an axial passage, a body, a cam, a cam tail, a stem engagement element, and a piston. A method of setting and testing a packoff seal comprises rotating the stem relative to the body to a delivery position, thereby disengaging the engaging element from the stem. The stem moves axially downward relative to the body to land the packoff. The engagement element reengages the stem in a landing position. Fluid pressure is applied to the axial passage to set and seal the packoff, thereby moving the running tool to a set position.

Abstract: A system and method for verifying support hanger orientation within a wellhead housing. In an example, a profile is included at a designated location on an inner surface of the wellhead housing. When the support hanger is landed in the wellhead housing, an impression is taken of the inner surface of the wellhead housing from a reference location. Analyzing the impression can indicate the position of the support hanger within the wellhead housing. A running tool that can land the support hanger within the wellhead housing can be equipped with an impression block for taking the impression of the profile in the wellhead housing.

Abstract: A well pipe hanger is run and landed within a subsea wellhead assembly using a latching mechanism with an adjustable preload. The well pipe hanger has a latch ring having upward and downward facing shoulders secured to the outer diameter of the tubing hanger so that the latch ring may expand radially into a groove of the landing sub. The outer and inner diameters of the latch ring are larger at a center of the latch ring than at the upper and lower ends. The latch ring is configured to contract radially from a latched to an unlatched position in response to a predetermined overpull force. The predetermined overpull force is adjustable by adjusting the radial distance between an axial center of the latch ring and the outer diameter of the well pipe hanger.

Abstract: A running tool for landing a tubular hanger in a subsea wellhead housing or the like, installing an annulus seal assembly into a sealing annulus between the tubular hanger and the wellhead housing, and then pressure testing the seal assembly. The running tool includes an inner mandrel which comprises an upper end that is connectable to a running string, a generally cylindrical inner body which is movably connected to the inner mandrel and releasably connectable to the tubular hanger, a generally cylindrical lower body which is positioned around the inner body above the tubular hanger and connectable to the seal assembly, a generally cylindrical upper body which is positioned above the lower body and is connected to the inner body, an outer mandrel which is slidably supported on the upper body and is connected to the lower body, and a first pressure chamber.

Abstract: An apparatus for, and method of, lowering items from a drilling rig to a well located below it through the use of a landing string comprised of drill pipe having an enlarged diameter section with a shoulder, in combination with upper and lower holders having wedge members with shoulders that engage and support the drill pipe at the shoulder of the enlarged diameter section, the shoulder of the drill pipe and the shoulders of the wedge members being rotatable with respect to each other.

Abstract: A wellhead assembly including a wellhead housing. The wellhead housing comprises a throughbore having a recessed sealing area and a tubing hanger positioned in the throughbore. A seal is positioned between the wellhead housing and the tubing hanger, the seal being positioned so as to form a gap between the seal and the wellhead housing. The wellhead assembly can further include a seal energizer capable of moving relative to the seal in a manner that forces the seal against the wellhead housing to bridge the gap. A method of installing a tubing hanger into a throughbore of a wellhead housing is also disclosed.

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 wellhead assembly includes a housing with a bore. A hanger is lowered into the housing, the hanger having at least one downward facing load shoulder. An expandable load ring is carried on the hanger. When casing weight is applied to the hanger, the weight energizes the load ring, causing it to expand and thereby increase the contact area between a load shoulder on the load ring and a load shoulder on the housing. The shoulders create a path for the load to be transferred to the housing. The increase in contact area increases the load carrying capacity of the hanger. The load ring expansion is limited to elastic expansion to allow it to return to a retracted position when the casing weight is removed.

Abstract: A casing hanger nesting indicator generates a signal to notify personnel on the surface that a wellhead member has properly landed on a predetermined surface within the wellbore. The casing hanger nesting indicator comprises a signaling device such as an explosive charge or a frequency shift key wherein the noise or vibration of the signaling device travels through the wellbore, via the drilling conduit in some embodiments, up to the surface platform.

Abstract: A subsea wellhead assembly provides a positive indication of landing of a wellhead member and locking of a wellhead member to a wellhead. The subsea wellhead assembly includes at least one positive indicator assembly disposed within a wellhead member, and a communication line extending down a running string from a platform to a running tool disposed in a subsea wellhead. The at least one positive indicator assembly provides confirmation of setting of the wellhead member, and the communication line is in communication with the positive indicator assembly to communicate the confirmation of setting with the platform following setting of the wellhead member.

Abstract: A wear bushing having a lead impression block is landed axially above a casing hanger and actuated to test an elevation of lock ring grooves formed in a wellhead. Then, drilling operations are performed through the wear bushing. The wear bushing includes a first tubular member having an axis and a second tubular member coaxial with the first tubular member. The second tubular member moves down to actuate a lead impression assembly to measure an elevation within the wellhead with the lead impression block. After the drilling operations are completed, the deformed lead impression block is retrieved along with the wear bushing.

Abstract: A running tool sets a casing hanger packoff and ensures that the packoff is not pressure tested unless the proper setting stroke was made by the running tool. 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 test slot is located in the outer surface of the inner body. A limit pin is connected to the piston and is adapted to engage the test slot when the piston moves longitudinally relative to the inner body. The stem has a raised profile on a portion of its exterior surface.

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: Two functionally and physically integrated subsystems form a supplemental disaster preventive system for offshore oil wells. A multi-function well subsystem modifies the sea-floor and in-well equipment to provide maintenance access, tools to cap the well, seal/re-seal the well, drill/re-drill the well, kill the well from the top, improve BOP reliability, add BOP functional redundancy, improve the cementing process, incorporate a sea-floor pressure relief/diversion function and improve the well's life cycle safety. A dome top cylindrical sidewall structure encloses the well's sea-floor equipment providing improved structural strength as well as passive protection from natural/human induced disasters. An intrusion detection and response subsystem provides sensing, processing and communication devices to detect, track & classify the 3D aspects of air/surface/sub-surface objects around a specific oil well or group of oil wells and provides the means to evaluate and eliminate threats.

Abstract: A seal seals an annulus in a subsea assembly between a wellhead and a casing hanger landed on a shoulder within a bore of the wellhead. The seal includes a casing hanger seal ring disposed within the annulus. The seal ring engaged with an inner diameter surface of the wellhead, and engaged with an outer diameter surface of the casing hanger so that the seal ring prevents flow through the annulus. A lockdown slip ring is secured to a lower end of the seal ring so that, when the seal ring is energized, the lockdown slip ring engages a substantially smooth inner diameter surface portion of the wellhead and a substantially smooth outer diameter surface portion of the casing hanger to limit upwards axial movement of the casing hanger.

Abstract: A string of conduit extending from a subsea wellhead assembly to a surface wellhead assembly on a platform has a plurality of grooved profiles on an upper portion of the conduit. Each profile is spaced axially from another of the grooved profiles. After a lower end of the conduit is secured to the subsea wellhead assembly, the operator pulls on the conduit to apply a selected tension to the conduit. The operator attaches a support ring to the profile that was closest to and above a load shoulder in the surface wellhead assembly when the desired tension was reached. After landing the support ring on the load shoulder, the operator may cut off any excess portion of the upper portion of the conduit located above the support ring. A seal ring is set between the upper portion of the conduit and the surface wellhead 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 method of completing a subsea wellbore includes providing one or more conductor anchoring assemblies on an outer surface of a conductor; forming the subsea wellbore; positioning the conductor in the subsea wellbore; and energizing the one or more conductor anchoring assemblies into contact with the subsea wellbore, thereby stabilizing the conductor in the subsea wellbore. In yet another embodiment, the method further includes extending the subsea wellbore; positioning a casing inside the conductor, wherein the casing includes a casing anchoring assembly; and energizing the casing anchoring assembly into contact with the conductor.

Abstract: A high-pressure, high-temperature tieback system including a production casing tieback tool consisting of a ratchet-latch sleeve disposed in a recessed portion of an annular extension of increased wall thickness of the production casing tieback tool and a production casing mudline hanger disposed about the production casing tieback tool. The production casing tieback tool is configured to directly engage the production casing mudline hanger. The ratchet-latch sleeve is configured to directly engage a threaded axial segment of a tubular other than the production casing mudline hanger.

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

Abstract: A 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.