Abstract: A system and method for subsea drilling/completion. The system comprises a high-pressure riser extending from a semi-submersible platform to a subsea wellhead. A landing string extends along the insider of the riser, and has a surface blowout preventer and at least one subsea blowout preventer attached thereto. A tubing hanger running tool is run from the platform toward the wellhead. In one embodiment, hydraulic control for various functions of the tubing hanger running tool is communicated either through the tubing string or through the riser. In another embodiment, hydraulic control lines for the tubing hanger running tool extend from the platform to the tubing hanger running tool through an umbilical line, which may either run through the tubing string, inside the riser but outside the tubing string, or outside and alongside the riser.

Abstract: A subsea production system is disclosed. The subsea production system may comprise a well head, a tubing spool, a tubing hanger, an annulus, a production tree, and a bypass flow path.

Abstract: A running tool 10, a lockdown sleeve 27, and a seal ring 24 are provided for axially fixing upward movement of a tubular hanger with respect to a subsea wellhead. The running tool 10 includes a tool latching and unlatching mechanism 51 for axially connecting the running tool to the subsea wellhead housing, a tool force applicator 64 for exerting a downward setting force, and a sleeve latching mechanism 73 for securing the lockdown sleeve to the subsea wellhead housing 20. The seal 24 is provided between the lockdown sleeve and one of the tubular hanger and the wellhead housing. The method of the invention includes running the tool and sleeve in open water to the subsea wellhead housing, locking the tool to the housing, setting the seal, locking the sleeve to the housing, then retrieving the tool in open water.

Abstract: The seal assembly 10 seal between a subsea wellhead housing 12 and a casing hanger 16. A metal seal body 20 includes fingers 32 and 34 and one or more elastomeric seals 38. An upper seal body 64 may include threads for engagement with the metal seal body. According the method of the invention, an initial elastomeric seal is first formed, and fluid pressure is applied from above to set the high temperature metal seal.

Abstract: The horizontal spool tree assembly 10 controls fluid flow through a production tubing string 18 within a well. The horizontal spool tree assembly is adapted for use with a workover string for fluid communication with the tree assembly. The spool body 12 has a central bore 14 for receiving a tubing hanger 22 therein, with a production passageway extending laterally through the spool body to a production line 36. The spool body also includes an annulus passageway extending laterally through the spool body for fluid communication between the tubing annulus 16 and the annulus line 52. The spool tree assembly has improved porting for the production line and the annulus line, and also for both workover and crossover operations.

Abstract: A horizontal spool tree assembly includes a spool body or housing 12 and a tubing hanger 18, 118, 218, 318 supporting a tubing string in a well. An internal tree cap 20, 120, 220, 320 is provided within the central bore in the spool body. In some embodiments, the tree cap includes a central bore in communication with a production bore through the tubing hanger and the lateral bore extending to a production port in the spool body. First and second closure members may be provided in the tree cap.

Abstract: A running tool 10, a lockdown sleeve 27, and a seal ring 24 are provided for axially fixing upward movement of a tubular hanger with respect to a subsea wellhead. The running tool 10 includes a tool latching and unlatching mechanism 51 for axially connecting the running tool to the subsea wellhead housing, a tool force applicator 64 for exerting a downward setting force, and a sleeve latching mechanism 73 for securing the lockdown sleeve to the subsea wellhead housing 20. The seal 24 is provided between the lockdown sleeve and one of the tubular hanger and the wellhead housing. The method of the invention includes running the tool and sleeve in open water to the subsea wellhead housing, locking the tool to the housing, setting the seal, locking the sleeve to the housing, then retrieving the tool in open water.

Abstract: A tool is used for installing a string of casing in a well. The casing is supported by a casing hanger that lands on a landing shoulder of the wellhead assembly. A running mechanism is releasably secured to the casing hanger for landing the casing hanger and setting a casing hanger seal. A profile is formed in the wellhead assembly above the landing shoulder. The tool includes a body having an upper portion and a lower portion, the lower portion being secured to the running mechanism. A mandrel is mounted to the body for axial movement relative to the body, the mandrel having a threaded upper end for securing to a running string of conduit. A cam surface is formed on the mandrel. A plurality of dogs are mounted to the upper portion of the body in sliding engagement with the cam surface for movement in response to axial movement of the mandrel into engagement with the profile. While in the engaged position, the dogs resist upward movement of the casing hanger during cementing of the string of casing.

Abstract: A tubular connection 7 is provided for connecting an upper tubular member 10 with a lower tubular member 12. A radially movable latch body 20 is positioned outward of the tubular members. Outer load flanks 25 on the latch body are slidably engageable with inner load flanks 24 on the tubular members. A radially projecting member 32 and a corresponding guide recess 34 are provided for guiding the latch body with respect to one of the tubular members. A safety actuator 30 and corresponding mating surface 38 may also be provided for urging the latch body outward.

Abstract: The horizontal spool tree assembly 10 controls fluid flow through a production tubing string 18 within a well. The horizontal spool tree assembly is adapted for use with a workover string for fluid communication with the tree assembly. The spool body 12 has a central bore 14 for receiving a tubing hanger 22 therein, with a production passageway extending laterally through the spool body to a production line 36. The spool body also includes an annulus passageway extending laterally through the spool body for fluid communication between the tubing annulus 16 and the annulus line 52. The spool tree assembly has improved porting for the production line and the annulus line, and also for both workover and crossover operations.

Abstract: A tubular connection 7 is provided for connecting an upper tubular member 10 with a lower tubular member 12. A radially movable latch body 20 is positioned outward of the tubular members. Outer load flanks 25 on the latch body are slidably engageable with inner load flanks 24 on the tubular members. A radially projecting member 32 and a corresponding guide recess 34 are provided for guiding the latch body with respect to one of the tubular members. A safety actuator 30 and corresponding mating surface 38 may also be provided for urging the latch body outward.

Abstract: A tubing hanger positioned within the bore of a wellhead body has a vertical bore from which a tubing string may be suspended within a well bore. When the hanger is landed, a fluid passageway in the tubing hanger has one end in fluid communication with a passageway in the wellhead body and its other end connected to a pressure responsive downhole function. The poppet valve mounted in the passageway is urged closed, and when opened permits fluid pressure from a source to be supplied to the function.

Abstract: A sealing system for sealing with a generally cylindrical surface 52 of a tubular or another tool 50 includes an annular packer element 10, a wedge ring 60 having a substantially conical outer surface 62 configured to radially expand the packer element, and a positioner 40 for moving one of the packer element and wedge ring relative to the other packer element and wedge ring. The packer element 10 includes an first elastomeric seal body 20 axially supported on a first metal rib 14 extending radially from a metal base 12, and a second seal body 22 axially supported on a second metal rib 16. The second seal body 22 has an elasticity lower than that of the first seal body. According to the method of the invention, the positioner is moved to cause the first seal body 20 to sealingly engage the cylindrical surface, and hydraulic forces due to that sealing engagement then move the packer element to the expanded diameter sealing position, in which the second seal body 22 seals against the cylindrical surface.

Abstract: The ball valve assembly 10 includes a valve body 12, a ball 14, a seat ring 30, a support ring 40, and an actuator sleeve 50 surrounding the ball and axially moveable within the valve body for rotating the ball between the open position and the closed position. A plurality of seals seal with the seat ring, the actuator sleeve, the support ring, and the valve body. The actuator sleeve 50 maintains fluid pressure within the valve body. The ball, support ring and seat ring are each formed from a selective material to enhance life of the ball valve assembly. A pair of pins 80, 82 each extend in a slot within the ball and holes in the sleeve, and preferably the pair of pins and the ball rotate with respect to the sleeve as the sleeve moves axially within the valve body.

Abstract: A tubing hanger adapted to be lowered into a landed position within the bore of a wellhead body has a vertical bore from which a tubing string may be suspended within a well bore, a fluid passageway which, when the hanger is landed in the bore of the body, is oriented into a desired rotational position in which one end is in fluid communication with one end of a fluid passageway in the body and its other end connects to a pressure responsive downhole function of a well production system, and in which a poppet valve mounted in the passageway is urged to closed position prior to lowering of the tubing into the bore, but adapted, when open, to permit fluid pressure from the source to be supplied to the function.

Abstract: The ball valve assembly 10 includes a valve body 12, a ball 14, a seat ring 30, a support ring 40, and an actuator sleeve 50 surrounding the ball and axially moveable within the valve body for rotating the ball between the open position and the closed position. A plurality of seals seal with the seat ring, the actuator sleeve, the support ring, and the valve body. The actuator sleeve 50 maintains fluid pressure within the valve body. The ball, support ring and seat ring are each formed from a selective material to enhance life of the ball valve assembly. A pair of pins 80, 82 each extend in a slot within the ball and holes in the sleeve, and preferably the pair of pins and the ball rotate with respect to the sleeve as the sleeve moves axially within the valve body.

Abstract: The seal assembly 10 seal between a subsea wellhead housing 12 and a casing hanger 16. A metal seal body 20 includes fingers 32 and 34 and one or more elastomeric seals 38. An upper seal body 64 may include threads for engagement with the metal seal body. According the method of the invention, an initial elastomeric seal is first formed, and fluid pressure is applied from above to set the high temperature metal seal.

Abstract: A sealing system for sealing with a generally cylindrical surface 52 of a tubular or another tool 50 includes an annular packer element 10, a wedge ring 60 having a substantially conical outer surface 62 configured to radially expand the packer element, and a positioner 40 for moving one of the packer element and wedge ring relative to the other packer element and wedge ring. The packer element 10 includes an first elastomeric seal body 20 axially supported on a first metal rib 14 extending radially from a metal base 12, and a second seal body 22 axially supported on a second metal rib 16. The second seal body 22 has an elasticity lower than that of the first seal body. According to the method of the invention, the positioner is moved to cause the first seal body 20 to sealingly engage the cylindrical surface, and hydraulic forces due to that sealing engagement then move the packer element to the expanded diameter sealing position, in which the second seal body 22 seals against the cylindrical surface.

Abstract: A running tool is used to install a load shoulder and a wear bushing in a subsea wellhead. A subsea wellhead has a locator shoulder, and grooved upper and lower profiles. The running tool has a cylindrical wear bushing that lands on a locator shoulder provided in the bore above a grooved lower profile in a wellhead housing. The running tool also carries a load shoulder ring and a split lock ring. The installation process consists of preparing the tool before running the tool subsea. Flowby ports on the running tool remain open during installation to speed the trip-in operation. The flowby ports are closed by lowering the central mandrel after the running tool lands. Then a portion of the wear bushing is moved downward, which in turn pushes the load shoulder out into the lower grooved profile to retain the load shoulder ring and wear bushing with the wellhead.

Abstract: A caisson wellhead system having a weak point wherein the wellhead system may be installed in a well as a single unit. The caisson wellhead system of the invention includes a lower tubular member having an upper rim. A lower rim of an upper tubular member is placed on the upper end of the lower tubular member. A removable connector is installed inside of and between the lower tubular member and upper tubular member for temporarily connecting the upper tubular member and the lower tubular member. A weak point is formed at the interface between the lower tubular member and the upper tubular member when the removable connector is removed. Therefore, the caisson wellhead system will break at a controlled location if any external components of the well equipment are struck by a foreign object such as an iceberg.