Abstract: Foldable pipe-in-pipe composite tubular structure having between pipes after rounding and hardening a filling material associating the layers to enhance the structure mechanical performance mostly in collapse resistance.

Abstract: Composite tubular casing with hardened material between thin pipe-in-pipe increasing the bending capability of the casing wall delivers high collapse resistance. Solid Expandable technology allows substantial wellbore slimming at the expense of collapse resistance. By combining both technologies, cost effective high collapse resistance wellbore construction can be achieved.

Abstract: A casing junction member connects in a well between a main casing and a lateral branch casing. The junction member has an upper end section which connects to the main casing extending above the member. It has a lower end section that is coaxial and connects into the main casing below the junction member. The junction member has a lateral section which extends downward for connecting to lateral branch casing. The junction between the main section and the lateral section has enlarged sections that are formed by opposed cones. A removable or drillable closure member blocks the lateral passage while in the collapsed and expanded positions. The casing junction uses internal fluid pressure to move from collapsed position to expanded position.

Abstract: A casing junction member connects in a well between a main casing and a lateral branch casing. The junction member has an upper end section which connects to the main casing extending above the member. It has a lower end section that is coaxial and connects into the main casing below the junction member. The junction member has a lateral section which extends downward for connecting to lateral branch casing. The junction between the main section and the lateral section has enlarged sections that are formed by opposed cones. A removable or drillable closure member blocks the lateral passage while in the collapsed and expanded positions. The casing junction uses internal fluid pressure to move from collapsed position to expanded position.

Abstract: Casing is installed in a well in a folded collapsed condition by uncoiling it from a reel. Two strings of tubing extend continuously through the collapsed casing. One of the strings of tubing is connected to a cement shoe at the lower end of the casing. An opening tool is located above the cement shoe and includes a piston. The other string of tubing extends to a pressure chamber that is between the piston and the cement shoe. After the casing is lowered with a running tool to the desired depth, cement is pumped down the first string of tubing, which flows back up the annulus surrounding the casing. A liquid is then pumped down the second string of tubing into the pressure chamber, causing the piston to push the opening head upward relative to the casing and the strings of tubing. The forming head opens the casing from the collapsed condition into a cylindrical configuration. The running tool retrieves the strings of tubing, opening tool and piston at the conclusion of the opening process.

Abstract: According to the invention, the tubular preform is radially deformable between a longitudinally folded state and substantially cylindrical unfolded state to form a length of rigid tube in situ. The preform comprises a flexible and watertight inner envelope (6) whose peripheral extent is equal to the internal extent of the length of tube, and, formed on the outside of said inner envelope, reinforcement (2) made of filamentary structure comprising a plurality of fibers impregnated with a settable resin, including fibers (3) oriented mainly in the peripheral direction of the preform, each of these fibers (3) extending over more than one turn and co-operating with adjacent fibers by making contact therewith such that adjacent fibers can slide over one another while the preform is in any state other than its unfolded state where, under internal pressure, the fibers are locked together by the friction between them due to a capstan effect.

Abstract: A cuttings collector will collect cuttings generated while drilling through conductor pipe for the first string of casing. The cuttings collector has a riser that secures to the exterior of an outer wellhead housing. A cage surrounds the riser. Ports at the upper end of the riser allow cuttings to flow out the riser and back down into the cage. A funnel guide locates at the upper end of the riser to guide the drill bit and the lower end of the first string of the casing. The running tool for the first string of casing lands an inner wellhead housing in the outer wellhead housing and simultaneously engages the cuttings collector to retrieve it. Cuttings from the collector will be dumped from the cuttings collector near the surface. The cuttings collector telescopes from an extended to a collapsed position for storage.

Abstract: A subsea well assembly has a cement port closure sleeve which opens and closes a cement port in an outer wellhead housing. The outer wellhead housing secures to conductor pipe. An inner wellhead housing is lowered into the outer wellhead housing before the well is drilled past the conductor pipe, and without having any casing secured to the inner wellhead housing. The sleeve opens and closes an inner return port that extends through the inner wellhead housing and which registers with the outer return port once the inner wellhead housing is in place. Drilling through the inner wellhead housing takes place with the sleeve closed. Subsequently, when casing is run, the casing hanger will engage the sleeve and move it to an open position. This allows cement returns to flow out the inner and outer return ports.

Abstract: A subsea well assembly utilizes outer, intermediate, and inner wellhead housings. The inner wellhead housing has a port extending through it that communicates the annulus with the bore of the inner wellhead housing. A sleeve mounts to the inner wellhead housing for opening and closing the port. The port allows the operator to cement a string of inner casing, with returns flowing through the port and back up the bore of the inner wellhead housing.

Abstract: A telescoping joint for connecting casing between a subsea housing and a surface wellhead can be reenergized. The telescoping joint includes an upper conduit section and a lower conduit section that telescopingly insert within one another. A seal locates in an annular space between the two conduit sections. A torque nut secures between the upper and lower conduit sections. The torque nut bears against the seal. The torque nut has a slot in its bore that is engaged by a running tool lowered from a drilling vessel at the surface. The running tool rotates the torque nut to energize the seal. A ratcheting lock ring locks the telescoping joint against withdrawing movement.

Abstract: A casing hanger seal member has a locking section that will lock the seal member to the casing hanger and to the wellhead housing. The locking section includes a lower split ring that has serrations that will engage serrations on the exterior of the casing hanger. An energizing ring will force the split ring outward after the seal has set. The energizing ring also forces an upper split ring radially. The upper split ring has serrations that engage serrations formed in the bore of the wellhead housing. Tapered load shoudlers on the energizing ring and lower split ring transmit a downward force to assure that the seal member sets before the locking section actuates. A detent shoulder formed in the locking section and on the energizing ring will releasably lock the energizing ring in a lower, set position.

Abstract: A running tool will set a packoff between a casing hanger and a wellhead housing utilizing weight and hydraulic pressure. The running tool has a mandrel which connects to the drill string. A lower and an upper body are carried by the mandrel. The lower body releasably connects to the casing hanger for supporting the casing hanger as it is lowered into the well. The packoff mounts to the upper body. An elastomeric seal locates on the upper body of the packoff. The upper body will move downward relative to the lower body once the casing has been cemented. In this lower position, weight of the drill string transmits from a collar to the elastomeric seal to form a seal against the wellhead housing. Hydraulic pressure may then be applied. The hydraulic pressure creates a force on the upper body to set the packoff. The running tool along with the elastomeric seal will be retrieved to the surface.

Abstract: A wear bushing for a casing hanger mounts to the bore of a casing hanger before the casing hanger is lowered into the well. The running tool for running the casing connects to the wear bushing. The wear bushing has a setting ring that connects to the seal for the casing hanger. The running tool has a setting sleeve that connects to the setting ring. The running tool will release from the wear bushing and the setting ring after the casing has been cemented and the seal set.

Abstract: The retrieving tool for retrieving a packoff from a casing hanger located in a subsea well has a pressure intensifying assembly. The retrieving tool has a mandrel which is connected to a string of conduit lowered from a floating vessel. A body is carried by the mandrel for landing on the casing hanger. A mandrel piston is located on the mandrel for movement with the mandrel and sealingly engages the bore of the body. This results in a pressure chamber above the mandrel piston, which is filled with a hydraulic fluid. A retrieving piston has a retrieving sleeve that latches into the packoff. The retrieving piston is carried above the mandrel piston in fluid communication with the pressure chamber. The pressure areas of the retrieving piston and the mandrel piston are dimensioned so that an increase of pressure due to movement of the mandrel piston will cause a greater force to be exerted by the retrieving piston.

Abstract: A casing hanger seal member has a locking section that will lock the seal member to the casing hanger, to the wellhead, or to both. A set of serrations are formed on the wellhead and also on the casing hanger, across from each other. The seal member has a seal on its lower end that seals below the serrations. A locking section extends upward from the seal section. A locking section has inner and outer walls which are separated by an annular channel. Serrations are formed on the inner and outer walls for engaging the serrations on the wellhead and the casing hanger. An energizing ring locates within the channel, urging the inner and outer walls radially apart form each other to cause engagement of the serrations. The serrations on the inner and outer members have a pitch that is the same as the pitch on the wellhead and casing hanger, divided by a whole number greater than one.

Abstract: A tool for setting a packoff between the casing hanger and the wellhead utilizes differential area pistons. The tool has a mandrel which connects to a string of drill pipe. The mandrel carries a body and is axially movable relative to the body. A setting sleeve is carried by the body for connection to the packoff. A setting sleeve piston is carried by the body for relative movement relative to the body. A mandrel piston is carried by the mandrel for movement with the mandrel. Passages in the body communicate the mandrel piston with a setting sleeve piston and contain an incompressible fluid. Downward movement of the mandrel causes the pressure to increase to drive the setting sleeve piston downward to set the packoff.

Abstract: A mechanism for locking a casing in a stationary support has an intermediate element which can move elastically in a receptacle of the support. The receptacle has upper and lower conical flanks. Conical inner grooving of the intermediate element has conical flanks of an angle at the apex greater than the angle at the apex of the upper flanks of the receptacle and less than the angle at the apex of the corner flank. The resultants of the forces to which the intermediate element is subjected has a radial component. When pulled upward, the radial component is outward. Under a downward force, the radial component is inward.

Abstract: A tool for setting the packoff between the casing hanger and the wellhead utilizes differential area pistons. The tool has a mandrel which connects to a string of drill pipe. The mandrel carries a body and is axially movable relative to the body. A setting sleeves is carried by the body for connection to the packoff. A setting sleeve piston is carried by the body for relative movement relative to the body. A mandrel piston is carried by the mandrel for movement with the mandrel. Passages in the body communicate the mandrel piston with a setting sleeve piston and contain an incompressible fluid. Axial movement of the mandrel causes the pressure to increase to drive the setting sleeve piston downward to set the packoff.

Abstract: A pin and box connection for connecting tubular members together utilizes a split sleeve. The split sleeve is carried on one of the members and has the ability to retract. This allows the members to be snapped together without rotation. The split sleeve is threaded, and the threads ratchet over each other when snapped together. A locking pin is located in one of the members for engaging a longitudinal slot in the other member. The locking member prevents the members from rotating to unscrew once snapped together. The locking pin can be removed to allow the members to be unscrewed from each other.

Abstract: A connector for connecting two pipes has threads configured to improve making up in severe motion conditions. The connector includes a pin and a box, each having frusto-conical surfaces with helical threads formed on them. The threads have multiple starts for rapid make up. The crest of each thread is truncated and is a frusto-conical surface. This frusto-conical surface is inverted to the frusto-conical surface of the portions of the pin and box that contain threads. Each thread has a load flank and a stabbing flank. The stabbing flank inclines and joins a link flank, which in turn joins a root. The link flank inclines at a different and steeper angle than the stabbing flank.