Abstract: Systems and methods include a plug activated mechanical isolation device that controls fluid flow inside a tubular in a wellbore. The device includes a sleeve for coupling to the tubular, and the sleeve includes an internal bore and port for fluid flow therethrough. A channel element is positioned in the internal bore and includes an internal channel and an orifice for fluid flow between the internal channel and internal bore. The channel element is attached to the sleeve via a breakable attachment portion, and the orifice is aligned with at least one port of the sleeve. The channel element is slidable within the sleeve, upon breakage of the breakable attachment portion with a force, to move the orifice out of alignment with the port of the sleeve so that a portion of the channel element covers the port of the sleeve to block fluid flow through the port.

Abstract: Systems and methods include a plug activated mechanical isolation device that controls fluid flow inside a tubular in a wellbore. The device includes a sleeve for coupling to the tubular, and the sleeve includes an internal bore and port for fluid flow therethrough. A channel element is positioned in the internal bore and includes an internal channel and an orifice for fluid flow between the internal channel and internal bore. The channel element is attached to the sleeve via a breakable attachment portion, and the orifice is aligned with at least one port of the sleeve. The channel element is slidable within the sleeve, upon breakage of the breakable attachment portion with a force, to move the orifice out of alignment with the port of the sleeve so that a portion of the channel element covers the port of the sleeve to block fluid flow through the port.

Abstract: Systems and methods include a mechanical isolation device that comprises a sleeve, which includes a port for fluid flow between an internal bore of the sleeve and an inside of a tubular. A receiver positioned in the internal bore includes a first orifice at a first axial location on the receiver, and a second orifice at a second axial location on the receiver. The second orifice is either aligned or un-aligned with the port of the sleeve. The receiver is slidable within the sleeve to: (i) move the first orifice into alignment with the port and either move the second orifice out of alignment with the port or keep the second orifice out of alignment with the port; and (ii) move the first orifice out of alignment with the port so that a portion of the receiver covers the port to block fluid flow between the internal bore of the sleeve and the port.

Abstract: An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod.

Abstract: Systems and methods include a mechanical isolation device that comprises a sleeve, which includes a port for fluid flow between an internal bore of the sleeve and an inside of a tubular. A receiver positioned in the internal bore includes a first orifice at a first axial location on the receiver, and a second orifice at a second axial location on the receiver. The second orifice is either aligned or un-aligned with the port of the sleeve. The receiver is slidable within the sleeve to: (i) move the first orifice into alignment with the port and either move the second orifice out of alignment with the port or keep the second orifice out of alignment with the port; and (ii) move the first orifice out of alignment with the port so that a portion of the receiver covers the port to block fluid flow between the internal bore of the sleeve and the port.

Abstract: A system and method for controlling fluid flow inside a tubular in a wellbore includes a tubular comprising an internal bore and a latch profile on an inner surface of the tubular. A receiver is positioned within the internal bore of the tubular at the latch profile so that the tubular and the receiver form a unit for insertion into the wellbore. An interior of the receiver defines a fluid flow channel, and the fluid flow channel includes an internal taper. A float valve is provided for dropping into the wellbore and the receiver. The float valve includes an external taper at an external surface of the float valve, and the external taper abuts against the internal taper of the receiver so that the float valve in the receiver blocks the fluid flow channel.

Abstract: An apparatus, system, and method of use enable control of fluid flow in a wellbore tubular. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball.

Abstract: An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod.

Abstract: An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod.

Abstract: An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod.

Abstract: An apparatus, system, and method of use enable control of fluid flow in a wellbore tubular. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball.

Abstract: A load lifting apparatus comprises a first housing, a second housing and a mechanical obstruction structure(s). The first housing is sized to slide over an upset tubular having a given diameter, wherein the first housing comprises the mechanical obstruction structure(s) that is designed to move radially inward when engaged with the second housing. The compressed internal diameter of the mechanical obstruction structure(s) can contact the upset tubular, wherein the upset tubular can then be supported by the mechanical obstruction structure(s) and the second housing, for safely lifting the upset tubular.

Abstract: A load lifting apparatus comprises a first housing, a second housing and a mechanical obstruction structure(s). The first housing is sized to slide over an upset tubular having a given diameter, wherein the first housing comprises the mechanical obstruction structure(s) that is designed to move radially inward when engaged with the second housing. The compressed internal diameter of the mechanical obstruction structure(s) can contact the upset tubular, wherein the upset tubular can then be supported by the mechanical obstruction structure(s) and the second housing, for safely lifting the upset tubular.

Abstract: A cylindrical ring sized to slide over the box end of an oilfield tubular having a given diameter, has a shoulder at one its ends and a sidewall along its length. The sidewall has a circumferential groove about its interior surface housing a band which can be made tight against the exterior surface of the oilfield tubular by a latch accessible through a slot in the sidewall, and which becomes even tighter if the tubular attempts to escape from the band. In a first orientation, the cylindrical ring is used as a load ring. By turning the cylindrical rings upside down, the cylindrical ring is used as a thread protector for the pin end of the tubular.

Abstract: A multi-functional apparatus and method for drilling fluid and cementing operations to set casing in a wellbore for use on either top drive or rotary type rigs. The apparatus and method includes a fill-up and circulating tool, a cementing head assembly, and a wiper plug assembly. The fill-up and circulating tool comprises a mandrel with a sealing element disposed about the outside diameter of the mandrel. The cementing head and wiper plug assemblies are useable on any fill-up and circulating tool capable of being inserted into a casing. To fill the casing, the assembly is lowered from the rig such that a portion of the fill-up tools inserted into the casing, the pumps are then actuated to flow fluid into the casing. To circulate fluid, the tool is lowered further such that the sealing element sealingly engages the inside diameter of the casing to allow fluid to flow through the casing, into the wellbore, and back to the fluid pumps.

Abstract: Embodiments disclosed herein relate to an apparatus to fluidly couple to a casing string. The apparatus may include a fill-up and circulating tool having a flow path extending therethrough, in which the fill-up and circulating tool may be configured to fluidly seal internally within an upper end of the casing string. The apparatus may further include a cementing head assembly having a flow path extending therethrough, in which the flow path of the cementing head assembly is fluidly coupled to the flow path of the fill-up and circulating tool, and a releasing mechanism coupled to the cementing head assembly, in which the releasing mechanism is configured to release a fluid-conveyed sealing device through the cementing head assembly and into the fill-up and circulating tool.

Abstract: Embodiments disclosed herein relate to an apparatus to fluidly couple to a casing string. The apparatus may include a fill-up and circulating tool having a flow path extending therethrough, in which the fill-up and circulating tool may be configured to fluidly seal internally within an upper end of the casing string. The apparatus may further include a cementing head assembly having a flow path extending therethrough, in which the flow path of the cementing head assembly is fluidly coupled to the flow path of the fill-up and circulating tool, and a releasing mechanism coupled to the cementing head assembly, in which the releasing mechanism is configured to release a fluid-conveyed sealing device through the cementing head assembly and into the fill-up and circulating tool.

Abstract: A cylindrical ring sized to slide over the box end of an oilfield tubular having a given diameter, has a shoulder at one its ends and a sidewall along its length. The sidewall has a circumferential groove about its interior surface housing a band which can be made tight against the exterior surface of the oilfield tubular by a latch accessible through a slot in the sidewall, and which becomes even tighter if the tubular attempts to escape from the band. In a first orientation, the cylindrical ring is used as a load ring. By turning the cylindrical rings upside down, the cylindrical ring is used as a thread protector for the pin end of the tubular.

Abstract: Embodiments disclosed herein relate to an apparatus to fluidly couple to a casing string. The apparatus may include a fill-up and circulating tool having a flow path extending therethrough, in which the fill-up and circulating tool is configured to fluidly couple to an upper end of the casing string, a cementing head assembly having a flow path extending therethrough, in which the flow path of the cementing head assembly is fluidly coupled to the flow path of the fill-up and circulating tool, and a releasing mechanism coupled to the cementing head assembly, in which the releasing mechanism is configured to release a fluid-conveyed sealing device through the cementing head assembly and into the fill-up and circulating tool.

Abstract: Methods for gripping an oilfield tubular include engaging a band with a ring member to form a load ring. The band has an arcuate component with a gap separating first and second ends, an interior surface, and an inclined exterior surface. The ring member has an interior surface with a groove therein. The inclined exterior surface of the band is associated with the groove of the interior surface to form the load ring. The load ring can be engaged with an oilfield tubular, and a force can be applied such that the groove of the ring member engages the inclined exterior surface of the band for securing the load ring to the oilfield tubular.