Abstract: Disclosed is a method and apparatus comprising a side drive system with a drive shaft (24, 24a) driven from the platform level (10) and powering a drilling unit (16) for rotating drill pipe (14). Except for the tethering of the drive shaft at the top of the derrick (60-64) and its coupling to a power source (70) at the platform level, there is preferably no stabilizing means for the system. The drive shaft (24, 24a) is stationary, preferably hollow, and extends the height of the derrick located to one side of the main drilling axis. The power source (70) at the platform level comprises a power takeoff from a conventional rotary table (84). The upper drive assembly (18) of the drilling unit (16) is coupled to the drive shaft (24, 24a) and capable of vertical movement along the drive shaft and providing torque to the drill string.

Abstract: Composite tubing connector assemblies (10, 10a) comprising elongated tubes (14, 14a) of composite material, with liners (12, 12a) and with the tube having upsets (16, 16a) formed by compression rings (20, 20a) located near each end of the composite tubes and end fittings such as a connector pin (22) and connector box (24) positioned over the upsets (16, 16a) and locked in place by split nuts (26, 26a), pressing the upsets (16, 16a) against the compression rings (20, 20a) within the end fittings. When coupled together in end-to-end relationshiop, a seal ring (26) is placed between the assemblies (10, 10a) to form a liner-to-liner seal. This arrangement allows the composite tube (14) to be formed and the end fittings (22, 24) coupled thereto at a later date, if desired.

Abstract: A tensioner unit (12) comprising an inner cylinder (22), filled partially with hydraulic fluid, with a piston (26) and piston rod (28) reciprocal therein (sometimes referred to as a hydraulic cylinder) surrounded by a cylindrical chamber (40) (sometimes referred to as an accumulator) for hydraulic fluid and gas. The gas in accumulator (40) is pressurized to maintain the hydraulic fluid under pressure against the piston (26) placing the piston rod (28) under tension to provide the necessary tension force on a marine riser (14) and to compensate for the rise and fall of a floating platform. This is a self-contained integral unit with one end of the piston rod (28) connected to the riser (14), and the other end connected to a frame (16) supported on a platform of a TLP. A plurality of such tensioner units (12) on this frame (16) and connected to said riser (14) form a complete riser tensioner (10) without external accumulators.

Abstract: A rotating and indexing mechanism (10) having two spaced apart, rows of toothed profiles (48, 52) which form camming surfaces for two spaced apart rows (62, 64) of cam followers (32). The toothed profiles (48, 54) and cam followers (32) are such that when there is relative movement between the toothed profiles (48, 54) and the rows (62, 64) of cam followers (32) in one direction, the camming action of the cam followers and toothed profiles pause incremental rotation of a shaft (16). A groove (66) is also provided for locking the two profiles and cam followers together when the desired incremental (index) position is reached.Two embodiments are shown, one where the toothed profiles are moved axially to give rotation to the cam followers and shaft, and the other where the cam followers move axially to give rotation to the toothed profiles and the shaft.

Abstract: A gate valve having a metal-to-metal seal between the gate (26) and the seat carrier (20) and a metal-to-metal seal between the seat carrier (20) and the valve body (10) with the seat carrier and valve body having complementary spaced frustoconical surfaces (18,22).

Abstract: A method for a cutting locking tab 56 and tool for a selected configuration on a joint (a pin (12a) and box (16a) threaded together). The pin has longitudinal slot(s) 24a and the box (16a) has inner and outer peripheral grooves (44,46) forming shear lines (50) to enhance the shearing to form the locking tab (56).The essential feature is the elimination of clocking, i.e., a predetermination of the relative orientation of the box and pin during manufacture.

Abstract: Disclosed is a production tree (10) with a top block (mandrel) (12) of the tree provided with a cone-shaped male connector member (14) which also functions as a manifold, and called a cone seal manifold, by having a plurality of shuttle valves (66) which, in the production mode connect umbilical hydraulic control lines (44) to valve actuator control lines (42). In the workover mode, a running tool (132) having a mating bell-shaped female connector member (134) engages the cone seal manifold (14) and moves the shuttle valves (66) to disconnect the umbilical control lines (44) from the valve actuator control lines (42) and to open the valve actuator control lines (42) to rig hydraulic control lines in the running tool (132) through the mating cone seal surfaces (134,56). Normally closed passageways (112) in the cone (56) of the cone seal manifold (14) are opened by fluid pressure from the rig control lines.

Abstract: An apparatus and method including a swaging die (10) with an internal cone-shaped bore section which will swage a pipe (14) forced into such die and form the cone section (30) on the pipe. Within the swaging die (10) is an insert/ejector plate (32) of a diameter to fit within the bore of the pipe (14) and wherein high pressure fluid directed through the insert/ejector plate (32) to the inside wall of the pipe (14) expands the pipe thus forming a longer, more acceptable, cone section (30) capable of providing more thread length for later threading operation. After the expansion pressure is relieved, the insert/ejector plate (32) is used to force the pipe (14) out of the swaging die (14).

Abstract: A bi-directional metal-to-metal seal (10) comprising a ring with a pair of oppositely acting sealing elements (20 or 22) integral with the outer periphery of the ring. In one embodiment, two pairs of such sealing elements (20 and 22) are located on each end of the ring (as viewed in cross section) and are of a thickness to be resilient (springy) and deflectable when inserted in an interference fit relationship into a cylindrical wall or bore to be sealed. The first sealing element (24) has a curved outer surface (26) and with an opening (30) facing the main flow path of pressure fluid. The curved outer surface rolls inward against the cylindrical wall (42) while being inserted into the cylinder, partially closing the opening (30) but still allowing the pressure fluid to enter and urge the curved surface against the cylindrical wall.

Abstract: A gate valve (10) having a valve operator (40) fully contained within a valve body with means for communicating fluid under pressure to the valve operator (40) to move a gate (32) to a valve open or a valve closed position. The valve operator (40) is located within the gate chamber (30) and the gate (32) itself contains and forms part of the valve operator (40) and, thus, considerable space is conserved. In one embodiment, the means for communicating pressure fluid to the valve operator includes a manifold (16) to allow the valve body (12) to rotate as part of a drilling assembly yet be remotely controllable. In another embodiment, the manifold may be eliminated for the use of the valve does not require rotation.This invention introduces gate valve technology into drilling operations to displace ball valves as kelly cock valves.

Abstract: A pack-off assembly for a wellhead system including a tapered pack-off mounted on a pack-off nut (22) which has multi-start threads (40) for engaging similar mating multi-start threads (26) on a casing hanger (C). The casing hanger (C) is provided with a taper (20) which faces the surrounding cylindrical wall (16) of the wellhead (W) thus providing a tapered annulus (14). The pack-off, being tapered, is moved into the tapered annulus (14) by rotation of the pack-off nut (22) where the pack-off engages an abutment (30) and is compressed and expanded into sealing engagement with the internal (16) and external surfaces (20) on the wellhead (W) and casing hanger (C). In one embodiment, the multi-start threads (40, 26) on the running nut (22) and casing hanger (C) are tapered buttress threads and, in a second embodiment, the multi-start threads (40a, 26a) on the running nut 22 and casing hanger (C) are cylindrical square threads.

Abstract: A wellhead system having a casing hanger (C) with a first sealing surface (20) within a wellhead (W) with a second sealing surface (16) spaced from said first sealing surface (20) forming annulus (14) in combination with a pack-off assembly (P) including a wedge ring (42), which in this embodiment, supports a pack-off (64) which has a first metal-to-metal seal (S-1) which sealingly engages the first sealing surface (20) upon initial movement of the pack-off (64) into the annulus (14) and a second metal-to-metal seal (S-1) which sealingly engages the second sealing surface (16) upon further movement of the wedge ring (42) urging said second pack-off seal (S-2) radially outwardly towards the first sealing surface (20). Each metal-to-metal seal may be provided with elastomeric sealing means. Two types of metal-to-metal seals (S-1, S-2) and two types of lock down means, wicker ring (40) and split ring (10), are disclosed.

Abstract: A pack-off assembly (P) for a wellhead system (W) comprising of a pack-off nut (36) with a tapered pack-off (40). The pack-off nut (36), in one embodiment, contains an internally tapered split ring (44) having multi-start threads (46) for engaging similar mating multi-start threads (32) on the casing hanger (C). The casing hanger (C) external surface (20) is provided with a taper which faces the surrounding internal cylindrical wall (16) of the wellhead (W) thus providing a tapered annulus (14).The pack-off assembly (P) is lowered to the wellhead (W) in a running tool (T) where the pack-off (40) is moved into the tapered annulus (14) without rotation of the pack-off nut (36) and the pack-off nut (36) is stabbed over (the mating threads (32, 46) ratchet) by the weight of the tubing string.

Abstract: An upper marine riser package (10/10A) comprising a diverter (D) for diverting uncontrolled gas and return drilling mud therethrough, a flexible joint FJ for allowing tilting motion between a vessel and a riser string (RS), a self-tensioning slip joint (SJ) and riser rotation bearing joint (RB) suspended below said vessel (V) to compensate for vertical motion between a subsea well (W) and a floating vessel (V). The upper marine riser package (10/10A) is sized to be run through a confined opening such as a riser handling spider (HS) and rotary table (RT) and to be suspended and operated below the deck of the vessel (V). The upper marine riser package can be used to eliminate the conventional riser tensioners normally above the platform and can be used in combination with such conventional riser tensioners normally above the platform for deeper and deeper drilling opertion.

Abstract: A method and tool for a cutting locking tab 56 of a selected configuration on a joint (a pin (12a) and box (16a) threaded together). The pin has longitudinal slot(s) 24a and the box (16a) has inner and outer peripheral grooves (44,46) forming shear lines (50) to enhance the shearing to form the locking tab (56).The essential feature is the elimination of clocking, i.e., a predetermination of the relative orientation of the box and pin during manufacture.

Abstract: A guideline connector (30) capable of being inserted over the top of a guide post (12) and has releasable locking means (40) which responds to the guide post contour to resiliently lock the connector onto the guide post profile (22). The locking means includes means (82, 84) for inactivating the locking means to free the connector of the guide post (12) and for automatically resetting (80, 86) (reactivating) the locking means (40) for further use. The locking means is functionally responsive to the outer contour of the guide post (12).

Abstract: The collet-type connector (10) comprising an upper body member (20) having a plurality of collet segments (52), a cam ring (64) movable relative to the upper body member (20) to move said collet segments (52) into a detachable connection of the connector to a subsea wellhead (14, 14a). The cam ring (64) and collet segments (52) have sets of camming surfaces whereby a first set (86, 92) cooperate to pivot the collet segments (52) initially toward the wellhead (14, 14a) and whereby a second set (96, 104) serves to urge the collet segments (52) further to clamp the connector (10) to the subsea wellhead (14, 14a). When the second set (96, 104) of camming surfaces function, the first set (86, 92) no longer function to rotate the collet segments, thus reducing the power requirement for urging the collet segments (52) into clamping engagement to only one set at a time, even though both sets together serve to aid in holding the collet segments in clamping engagement with the wellhead after final engagement.

Abstract: A check valve system (10) with a fail-safe valve (FSC) comprising either a pair of oppositely acting, oppositely facing, one-way check valves (V1 and V2) located at the interface (42) between two connecting numbers (36, 40), or a shuttle valve (206) and stab (232), for controlling the flow of fluid through the connector members at the member interface. Said valves (V1, V2, and 206) are closed by spring bias when the members are separated but which are mechanically opened when said members engage one another to permit the flow of pressure fluid through the members. The fail-safe valve (FSC or FSCa) is a one-way check valve in one of the check valves (V2) closed against pressure fluid, when said members are joined, but which will open to relieve any pressure which might be trapped in control lines (12a) when the members become disconnected. The members are disclosed as part of a connector (16) and a mandrel (20), and as part of a tree (200), tree cap (202 ), or running tool.

Abstract: A pack-off (10) comprising of two metallic rings (12, 14) with a serpentine or undulating band (16) integral therewith embedded in elastomeric material (32). The lower metallic ring (14) is narrower than the upper metallic ring (12) and the serpentine band (16) and elastomeric material taper such that the narrow portion is at the lower end of the pack-off to engage and seal a tapered annulus (40) in a wellhead system. In one embodiment, the apices (20-26) of the serpentine band are curved and engage the side walls of a tapered annulus (40) to provide a combined metal-to-metal and elastomeric seal. In another embodiment, the apices (20a-26a) of the serpentine band (16) are flat to provide more metal contact with the side walls of the tapered annulus (10). The lower ring engages an abutment (52) and continued movement of the pack-off (10) deforms the band (16) and expands the elastomeric material (34) to seal the annulus (40).

Abstract: A conductor tieback connector (T) thus having a tubular body (12) connectible to the lower end of a conductor or a string of conductors (C), a downwardly extending funnel (20) with two bearing surfaces and a tapered guide (24). The tapered guide (24) aids in initial stabbing of the connector (T) over a wellhead (W) and the two bearing surfaces (26, 30) operate on the outside of the wellhead (W) to force the tieback connector (T) into angular alignment under the influence of the weight of the conductor string. Seals (14, 16), located between the tieback connector (T) and wellhead (W), are compressed with axial movement of the tieback connector (T). A two-piece internal floating bushing (42, 42a, 42b), threadible (50, 52) on the interior surface of the tieback connector (T), is moved within the interior of the wellhead (W) where locking dogs (46) engage running tool grooves (40) in the bore of the wellhead (W) to clamp the tieback connector (T) onto the wellhead (W).