Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet of a cement head including, without limitation, when the cement head is positioned at an elevated location above a rig floor.

Abstract: An anchor assembly for anchoring casing or other pipe against axial upward movement while permitting rotation of the casing or other pipe. An inner mandrel member has a central bore and a flange member extending around the outer circumference of the mandrel. A friction reducing ring member is located on an upper surface of the flange member, while layered friction reducing sleeve members are positioned around the outer surface of the mandrel member. An anchor sleeve member is concentrically and rotatably positioned around the outer surface of the outermost friction reducing sleeve member. Connection flanges, each having at least one bore for attachment to a shackle or other connecting device, extend laterally from the outer periphery of the anchor sleeve member and allow for anchoring of the assembly (and any attached casing or other pipe) to a rig or other structural support member.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet of a cement head including, without limitation, when the cement head is positioned at an elevated location above a rig floor.

Abstract: An auto-fill type float collar assembly is provided. The float collar assembly of the present invention has at least one curved flapper-style valve, preferably constructed of composite, non-metallic material. Each flapper of the present invention has a substantially 90° range of motion, and is closed via a torsion spring. Each flapper is held in the open (or “auto-fill”), position via an external shifting mechanism passing around, rather than through, the central flow bore of the assembly. A floatable actuation ball can be run with the tool, or pumped downhole, in order to selectively actuate the assembly and close the flappers when desired.

Abstract: A centralizer assembly having a tubular body member with upper and lower channels extending around the external surface of said central tubular body member. A bow spring assembly having bow spring members is installed around the outer surface of the tubular body member and can rotate about the outer surface of the central tubular body member. Bow spring heel supports prevent the bow spring members from contacting the outer surface of the central tubular member when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles. A robust bolster frame protects the centralizer assembly during shipping, storage or other periods of non-use.

Abstract: A centralizer assembly having a tubular body member with upper and lower channels extending around the external surface of said central tubular body member. A bow spring assembly having bow spring members is installed around the outer surface of the tubular body member and can rotate about the outer surface of the central tubular body member. Bow spring heel supports prevent the bow spring members from contacting the outer surface of the central tubular member when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles. A robust bolster frame protects the centralizer assembly during shipping, storage or other periods of non-use.

Abstract: A centralizer assembly having a tubular body member with upper and lower channels extending around the external surface of said central tubular body member. A bow spring assembly having bow spring members is installed around the outer surface of the tubular body member and can rotate about the outer surface of the central tubular body member. Bow spring heel supports prevent the bow spring members from contacting the outer surface of the central tubular member when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles. A robust bolster frame protects the centralizer assembly during shipping, storage or other periods of non-use.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet of a cement head including, without limitation, when the cement head is positioned at an elevated location above a rig floor.

Abstract: An auto-fill type float collar assembly is provided. The float collar assembly of the present invention has at least one curved flapper-style valve, preferably constructed of composite, non-metallic material. Each flapper of the present invention has a substantially 90° range of motion, and is closed via a torsion spring. Each flapper is held in the open (or “auto-fill”), position via an external shifting mechanism passing around, rather than through, the central flow bore of the assembly. A floatable actuation ball can be run with the tool, or pumped downhole, in order to selectively actuate the assembly and close the flappers when desired.

Abstract: An auto-fill type float collar assembly is provided. The float collar assembly of the present invention has at least one curved flapper-style valve, preferably constructed of composite, non-metallic material. Each flapper of the present invention has a substantially 90° range of motion, and is closed via a torsion spring. Each flapper is held in the open (or “auto-fill”), position via an external shifting mechanism passing around, rather than through, the central flow bore of the assembly. A floatable actuation ball can be run with the tool, or pumped downhole, in order to selectively actuate the assembly and close the flappers when desired.

Abstract: An anchor assembly for anchoring casing or other pipe against axial upward movement while permitting rotation of the casing or other pipe. An inner mandrel member has a central bore and a flange member extending around the outer circumference of the mandrel. A friction reducing ring member is located on an upper surface of the flange member, while layered friction reducing sleeve members are positioned around the outer surface of the mandrel member. An anchor sleeve member is concentrically and rotatably positioned around the outer surface of the outermost friction reducing sleeve member. Connection flanges, each having at least one bore for attachment to a shackle or other connecting device, extend laterally from the outer periphery of the anchor sleeve member and allow for anchoring of the assembly (and any attached casing or other pipe) to a rig or other structural support member.

Abstract: An apparatus for launching objects, such as during casing cementing operations, in wells having dual gradient fluid systems or certain downhole internal diameter restrictions. A launching assembly is located below a dual gradient valve or other restriction. In one embodiment, control lines extend from the earth's surface to the launching assembly and control actuation of the launching assembly. In an alternative embodiment, a receptacle assembly is positioned above a dual gradient valve or other restriction, with control lines extending from the receptacle assembly to the launching assembly. A dart or other triggering object is launched from the earth's surface to the receptacle assembly in order to control actuation of the launching assembly.

Abstract: A centralizer assembly having a tubular body member with upper and lower channels extending around the external surface of said central tubular body member. A bow spring assembly having bow spring members is installed around the outer surface of the tubular body member and can rotate about the outer surface of the central tubular body member. Bow spring heel supports prevent the bow spring members from contacting the outer surface of the central tubular member when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles. A robust bolster frame protects the centralizer assembly during shipping, storage or other periods of non-use.

Abstract: An auto-fill type float collar assembly is provided. The float collar assembly of the present invention has at least one curved flapper-style valve, preferably constructed of composite, non-metallic material. Each flapper of the present invention has a substantially 90° range of motion, and is closed via a torsion spring. Each flapper is held in the open (or “auto-fill”), position via an external shifting mechanism passing around, rather than through, the central flow bore of the assembly. A floatable actuation ball can be run with the tool, or pumped downhole, in order to selectively actuate the assembly and close the flappers when desired.

Abstract: An improved method and/or apparatus for completing a wellbore is provided. In one embodiment, a method of lining a pre-drilled wellbore is provided. The method includes the act of providing a casing assembly, the casing assembly including a string of casing; and a retractable joint comprising an inner tubular and an outer tubular. The method further includes the acts of running the casing assembly into the pre-drilled wellbore and actuating the retractable joint, thereby reducing the length of the casing assembly through movement between the inner and outer tubulars.

Abstract: Methods and apparatus are provided for reducing surge pressure while running casing into a wellbore. The apparatus includes a running string for running casing having a diverter tool therein. The diverter tool has one or more bypass ports between its upper and lower end which are normally closed. In operation, the diverter tool is automatically cycled between the open and closed positions of the bypass ports during a casing running operation. A pressure event inside the diverter tool deactivates the cyclic opening and closing function of the bypass port.