Abstract: A liner string for a wellbore includes a liner hanger assembly (LHA) and a liner hanger deployment assembly (LHDA) releasably attached to the LHA. The LHDA includes a central bore and a running tool moveable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore. The liner string further includes a chamber disposed between the LHDA and LHA, wherein the chamber is in selective fluid communication with the flow path. Wherein, when the flow path is closed, the chamber is isolated from the central bore, and when the flow path is open, the flow path provides fluid communication between central bore and chamber.

Abstract: A liner string includes a liner hanger assembly and a liner hanger deployment assembly. The liner hanger assembly includes a liner hanger. The liner hanger includes a plurality of slips and a liner hanger actuation assembly configured to set the plurality of slips. The liner hanger deployment assembly is disposed within the liner hanger assembly. The liner hanger deployment assembly includes a setting tool configured to selectively allow fluid communication between a central bore of the setting tool and the liner hanger actuation assembly.

Abstract: A liner string for a wellbore includes a liner hanger assembly (LHA) and a liner hanger deployment assembly (LHDA) releasably attached to the LHA. The LHDA includes a central bore and a running tool moveable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore. The liner string further includes a chamber disposed between the LHDA and LHA, wherein the chamber is in selective fluid communication with the flow path. Wherein, when the flow path is closed, the chamber is isolated from the central bore, and when the flow path is open, the flow path provides fluid communication between central bore and chamber.

Abstract: A liner string for a wellbore includes a liner hanger assembly (LHA) and a liner hanger deployment assembly (LHDA) releasably attached to the LHA. The LHDA includes a central bore and a running tool moveable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore. The liner string further includes a chamber disposed between the LHDA and LHA, wherein the chamber is in selective fluid communication with the flow path. Wherein, when the flow path is closed, the chamber is isolated from the central bore, and when the flow path is open, the flow path provides fluid communication between central bore and chamber.

Abstract: A liner string includes a liner hanger assembly and a liner hanger deployment assembly. The liner hanger assembly includes a liner hanger. The liner hanger includes a plurality of slips and a liner hanger actuation assembly configured to set the plurality of slips. The liner hanger deployment assembly is disposed within the liner hanger assembly. The liner hanger deployment assembly includes a setting tool configured to selectively allow fluid communication between a central bore of the setting tool and the liner hanger actuation assembly.

Abstract: Methods are disclosed for producing proteins having biological activity for blood coagulation mediated by Factor VIIa or Factor IX. The proteins are produced by mammalian host cells which have been stably transfected with a DNA construct containing a nucleotide sequence which codes at least partially for either Factor VII or Factor IX. The nucleotide sequence comprises a first nucleotide sequence encoding a calcium binding domain, joined to a second nucleotide sequence positioned downstream of the first sequence. The second sequence encodes a catalytic domain for the serine protease activity of either Factor VIIa or Factor IX. The joined sequences code for proteins having substantially the same biological activity for blood coagulation as either Factor VIIa or Factor IX.

Abstract: Methods and apparatus are provided to place a conductor pipe and a casing in a subsea environment. In one embodiment, a conductor pipe is jetted or drilled into the subsea floor. Thereafter, a casing drilling assembly comprising a drill casing and a drilling assembly is connected to the drill pipe using a crossover. The drilling assembly urged into the seafloor until a casing latch on the drilling assembly is engaged with a casing profile of the conductor pipe. During drilling, instrumentation in the drilling assembly may be used to measure geophysical data. The measured data may be used to optimize the drilling process. After the drill casing is engaged with the conductor pipe, cementing may be performed to set the drill casing.

Abstract: Methods and apparatus are provided to place a conductor pipe and a casing in a subsea environment. In one embodiment, a conductor pipe is jetted or drilled into the subsea floor. Thereafter, a casing drilling assembly comprising a drill casing and a drilling assembly is connected to the drill pipe using a crossover. The drilling assembly urged into the seafloor until a casing latch on the drilling assembly is engaged with a casing profile of the conductor pipe. During drilling, instrumentation in the drilling assembly may be used to measure geophysical data. The measured data may be used to optimize the drilling process. After the drill casing is engaged with the conductor pipe, cementing may be performed to set the drill casing.

Abstract: Methods and apparatus are provided to place a conductor pipe and a casing in a subsea environment. In one embodiment, a conductor pipe is jetted or drilled into the subsea floor. Thereafter, a casing drilling assembly comprising a drill casing and a drilling assembly is connected to the drill pipe using a crossover. The drilling assembly urged into the seafloor until a casing latch on the drilling assembly is engaged with a casing profile of the conductor pipe. During drilling, instrumentation in the drilling assembly may be used to measure geophysical data. The measured data may be used to optimize the drilling process. After the drill casing is engaged with the conductor pipe, cementing may be performed to set the drill casing.

Abstract: Apparatus and method for controlling pressure surges in a wellbore. One embodiment provides a downhole surge control tool equipped with a fluid motivator. The fluid motivator may be, for example, any type of motor or a venturi. The fluid motivator motivates wellbore fluid through a bypass channel formed in the tool and then out an exhaust port of the tool.

Abstract: A connector arrangement used for connecting and locking tubular members. The connector consists of two tubular members and a coupling member. The tubular members are threaded together to create a threaded connection. The locking arrangement is provided by a pathway formed on the tubular member whereby a locking member can be inserted in to the pathway to lock the threaded connection. The locking arrangement is also provided by a plurality of castellation members disposed on each tubular member. The connector also has a separate coupling member which has opposite right-hand and left-hand threaded ends to threadedly mate with the threads of the two tubular members.

Abstract: Apparatus and method for controlling pressure surges in a wellbore. One embodiment provides a downhole surge control tool equipped with a fluid motivator. The fluid motivator may be, for example, any type of motor or a venturi. The fluid motivator motivates wellbore fluid through a bypass channel formed in the tool and then out an exhaust port of the tool.

Abstract: The present invention provides a connector arrangement for connecting and locking tubular members. The connector consists of two tubular members and a coupling member. The tubular members are threaded together to create a threaded connection. The locking arrangement is provided by a pathway formed on the tubular member whereby a locking member can be inserted in to the pathway to lock the threaded connection. The locking arrangement is also provided by a plurality of castellation members disposed on each tubular member. The connector also has a separate coupling member which has opposite right-hand and left-hand threaded ends to threadedly mate with the threads of the two tubular members.

Abstract: The well reference apparatus and method of the present invention includes an anchor member with a orientation member preferably permanently installed within the borehole at a preferred depth and orientation in one trip into the well. The orientation member provides a permanent reference for the orientation of well operations, particularly in a multi-lateral well. The assembly of the present invention includes disposing the anchor member and orientation member on the end of a pipe string. An orienting tool such as an MWD collar is disposed in the pipe string above the anchor member. This assembly is lowered into the borehole on the pipe string. Once the preferred depth is attained, the MWD is activated to determine the orientation of the orientation member. If the orientation member is not oriented in the preferred direction, the pipe string is rotated to align the orientation member in the preferred direction.

Abstract: The liner assembly and method includes lowering a liner, liner hanger, liner hanger setting tool, liner packer, and liner packer setting tool into the borehole on a work string. The liner hanger is set either hydraulically or mechanically using the liner hanger setting tool at the option of the operator. The liner is then cemented within the borehole and the liner packer setting tool is used to set the liner packer either hydraulically or mechanically at the option of the operator. The liner packer setting tool includes an actuator assembly mounted on the exterior of a tubular body. The actuator assembly includes an actuator member having a contact member which engages the packing element on the liner packer such that upon movement of the contact member with respect to the liner packer, the packing element on the liner packer is compressed to sealingly engage the cased borehole. The actuator member is sealed from the fluid pressure within the borehole until the liner packer is to be set.

Abstract: Dimeric proteins having substantially the same biological activity as PDGF are disclosed. More specifically, the protein may have two substantially identical polypeptide chains, each of the chains being substantially homologous to the A-chain of PDGF. Alternatively, the protein may have two polypeptide chains that are substantially identical to the A-chain of PDGF. In addition, proteins comprising polypeptides that are variants or derivatives of the A-chain of PDGF are also disclosed. Therapeutic compositions containing these proteins and methods for enhancing the wound-healing process in warm-blooded animals are also disclosed.

Abstract: PDGF B-chain polypeptides characterized by the substitution or deletion of a lysine or arginine residue at position 27, 28, 32, 79, 80 or 81 of native B-chain are disclosed. Also disclosed are PDGF-like proteins containing the B-chain polypeptides. The polypeptides and proteins may be produced through the use of cultured cells transfected or transformed to express DNA molecules that encode the polypeptides. The PDGF-like proteins are useful as components of cell culture media and for accelerating the healing of wounds.

Abstract: PDGF B-chain polypeptides characterized by the substitution or deletion of a lysine or arginine residue at position 27, 28, 32, 79, 80 or 81 of native B-chain are disclosed. Also disclosed are PDGF-like proteins containing the B-chain polypeptides. The polypeptides and proteins may be produced through the use of cultured cells transfected or transformed to express DNA molecules that encode the polypeptides. The PDGF-like proteins are useful as components of cell culture media and for accelerating the healing of wounds.

Abstract: The liner packer assembly and method includes a liner packer having a tubular body with an aperture for the flow of wellbore fluids. A packing element is movably disposed on the tubular body between an open position on one side of the aperture for allowing wellbore fluids to flow through the aperture to a closed position on the other side of the aperture for closing flow through the aperture and for packing off the annulus between the packer and outer casing. During the cementing operation, drilling fluids and cement are allowed to flow through the annular area formed by the packer and outer casing and also flow through the aperture in the tubular body of the packer and up the inside diameter or inner annular area formed by the packer and inner tubular string. The inner and outer annular areas around packer approximately the flow area below the packer between the inner tubular string and the outer casing.

Abstract: The liner assembly and method includes lowering a liner, liner hanger, liner hanger setting tool, liner packer, and liner packer setting tool into the borehole on a work string. The liner hanger is set either hydraulically or mechanically using the liner hanger setting tool at the option of the operator. The liner is then cemented within the borehole and the liner packer setting tool is used to set the liner packer either hydraulically or mechanically at the option of the operator. The liner packer setting tool includes an actuator assembly mounted on the exterior of a tubular body. The actuator assembly includes an actuator member having a contact member which engages the packing element on the liner packer such that upon movement of the contact member with respect to the liner packer, the packing element on the liner packer is compressed to sealingly engage the cased borehole. The actuator member is sealed from the fluid pressure within the borehole until the liner packer is to be set.