Abstract: The present disclosure may comprise a valve used to control fluid flow. The valve may have an inlet and an outlet connected by a bore through which fluid may flow. A gate may be moveably configured within an internal cavity positioned along a length of the bore. The gate may move between an open position that allows fluid to flow through the gate, and a closed position that does not allow fluid to flow through the gate. Two elastomeric energizing assemblies may be configured on either side of the gate. Lantern rings with lantern ring openings may be configured concentrically with the elastomeric energizing assemblies. Valve seats may be configured between the elastomeric energizing assemblies and the gate. When fluid flows past the lantern ring openings, pressure may increase in the elastomeric energizing assemblies, causing the valve seats to compress against the gate and form a seal with the gate.

Abstract: A hanger assembly has at least one elongated channel disposed on the outer surface of the hanger assembly. An alignment/anti-rotation tab member is moveably disposed within each elongated channel and can selectively alternate between a first retracted configuration and a second extended configuration. In the second extended configuration, each alignment/anti-rotation tab member can be received within a mating channel along the inner surface of the central through bore of the wellhead. Each extended alignment/anti-rotation tab member can engage against a mating recess or channel in order to align and orient the hanger assembly within the central through bore of the wellhead (permitting orientation and alignment of ports in the hanger assembly and the surrounding wellhead), while also preventing rotation of the hanger assembly relative to the wellhead.

Abstract: A hanger assembly has at least one elongated channel disposed on the outer surface of the hanger assembly. An alignment/anti-rotation tab member is moveably disposed within each elongated channel and can selectively alternate between a first retracted configuration and a second extended configuration. In the second extended configuration, each alignment/anti-rotation tab member can be received within a mating channel along the inner surface of the central through bore of the wellhead. Each extended alignment/anti-rotation tab member can engage against a mating recess or channel in order to align and orient the hanger assembly within the central through bore of the wellhead (permitting orientation and alignment of ports in the hanger assembly and the surrounding wellhead), while also preventing rotation of the hanger assembly relative to the wellhead.

Abstract: In various implementations, a hydraulic fracturing piping system may include one or more rotatable elbows to connect other components of the hydraulic fracturing piping system. Using rotatable elbows may facilitate connections in the hydraulic fracturing piping system. For example, when using a rotatable elbow, in the assembly of the system, the rotatable elbow may be capable of rotating to different positions to facilitate alignment of the hydraulic fracturing manifold and hydraulic fracturing stack (e.g., christmas tree), when the hydraulic fracturing manifold and the hydraulic fracturing stack are not in alignment. In some implementations, the elbow may include an internal radial transition (e.g., of approximately 90 degrees) to control the media being injected into the wellbore. The internal radial transition of the elbow may create a more uniform media flow and/or less turbulence, which may significantly reduce erosion of the inner surfaces the bore of the elbow.

Abstract: In various implementations, a hydraulic fracturing piping system may include one or more rotatable elbows to connect other components of the hydraulic fracturing piping system. Using rotatable elbows may facilitate connections in the hydraulic fracturing piping system. For example, when using a rotatable elbow, in the assembly of the system, the rotatable elbow may be capable of rotating to different positions to facilitate alignment of the hydraulic fracturing manifold and hydraulic fracturing stack (e.g., christmas tree), when the hydraulic fracturing manifold and the hydraulic fracturing stack are not in alignment. In some implementations, the elbow may include an internal radial transition (e.g., of approximately 90 degrees) to control the media being injected into the wellbore. The internal radial transition of the elbow may create a more uniform media flow and/or less turbulence, which may significantly reduce erosion of the inner surfaces the bore of the elbow.

Abstract: A cage for a choke valve assembly and method for using the same is provided. The cage includes one or more teardrop shaped orifices for the manipulation of fluid flow through the choke valve assembly.

Abstract: A cage for a choke valve assembly and method for using the same is provided. The cage includes one or more teardrop shaped orifices for the manipulation of fluid flow through the choke valve assembly.

Abstract: A method for removing a tubular from a wellbore can include repeatedly and sequentially using an upper gripping member of an upper section and a lower gripping member of a lower section to hydraulically grip the tubular, while repeatedly and sequentially extending and retracting the upper section relative to the lower section to raise the tubular from the wellbore to a predetermined height. At least one lifting hole can be formed in the tubular, and a lifting member can be installed in each lifting hole. A hoist can be connected with each lifting member. The tubular can be cut using a saw and removed from the wellbore using the hoist.

Abstract: A tubular lift safety system can include a wellbore tubular removal system for removing tubulars from wellbores, which can have an upper section movable relative to a lower section. The upper section and the lower section can both have gripping members for gripping and releasing the tubulars while the upper section is moved relative to the lower section; thereby removing the tubulars from the wellbore. The upper section can have cutting devices for forming lifting holes and a saw for cutting the tubulars. A fluid source can control extension and retraction of the upper section relative to the lower section, operation of the gripping members, and operation of the saw. A remote control can monitor pressure from the fluid source.

Abstract: A wellbore tubular lift safety system and tubular lifting apparatus for removing tubulars can include a lower section with a lower base plate hole, sliding rods, and a lower gripping member. An upper section can have an upper base plate hole, a saw mounting plate hole, an upper gripping member, and cylinder barrels. The sliding rods can be engaged within the cylinder barrels, and can be moved therein for extending and retracting the upper section. The apparatus can be positioned over the wellbore in a retracted position to align with the tubular. The tubular can be lifted out of the wellbore by gripping the tubular using the gripping members, and extending and retracting the upper section. The apparatus can form lifting holes in the tubular, install lifting members in the lifting holes, saw the tubular, and allow the cut tubular to be lifted via a hoist.

Abstract: A method for manufacturing a creped fiber web is provided and includes providing a rotating cylindrical dryer surface, providing a creping adhesive composition or coating package having a pH boosted at least 0.5 pH units relative to its original base formulation pH in the range of from about 4.5 to about 9, for chemically setting a crosslinkable polymer component at least in part before applying the creping adhesive composition to the rotating cylindrical dryer surface to provide an adhesive dryer surface on which a fiber web can be transferred, dried, and creped.

Abstract: A method for manufacturing a creped fiber web is provided and includes providing a rotating cylindrical dryer surface, providing a creping adhesive composition or coating package having a pH boosted at least 0.5 pH units relative to its original base formulation pH in the range of from about 4.5 to about 9, for chemically setting a crosslinkable polymer component at least in part before applying the creping adhesive composition to the rotating cylindrical dryer surface to provide an adhesive dryer surface on which a fiber web can be transferred, dried, and creped.

Abstract: Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.

Abstract: Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.

Abstract: Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.

Abstract: Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.

Abstract: A method and apparatus for drilling and completing multiple wellbores from a single drilling rig and from within a single wellhead is provided. In one embodiment, a template is disposed at a predetermined location downhole within a casing. In one aspect, a first casing string is lowered with the template to the predetermined location and disposed within a first wellbore. A second wellbore may be drilled through a bore in the template. A second casing string may then be lowered through the bore into the second wellbore. In another embodiment, at least two wellbores are drilled and completed from a surface casing having a crossover portion.

Abstract: Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.