A cutting bit includes a bit body and high-pressure body with a high-pressure fluid conduit therethrough. The high-pressure body and bit body are joined together. The high-pressure fluid conduit is configured to convey a fluid at greater than 14.5 ksi, and in some embodiments greater than 40 ksi. The high-pressure fluid conduit may direct the fluid through a nozzle in a fluid jet to weaken material, such as an earth formation. The cutting bit includes at least one roller cone and/or blades with cutting elements thereon to remove the weakened material. A cutting bit includes both high and low-pressure fluid conduits, and high and low-pressure fluid nozzles. The high-pressure nozzles receive fluid flow from a downhole pressure intensifier, and a connection between the bit and the downhole pressure intensifier includes rigid connectors, flexible connectors, or a combination thereof.

A system includes production tubing, a telescoping joint, a pump sub, a lock ring, and a crossover. The production tubing provides a hydraulic connection from a surface location to a well. The telescoping joint has a housing and a by-pass hanger having a head. An opening of the housing is larger than the by-pass hanger and smaller than the head and the head is moveably located within the housing. The lock ring is disposed around the by-pass hanger directly beneath the opening of the housing. The lock ring absorbs a compressive force and prevents the by-pass hanger from moving in an upwards direction. The crossover component is hydraulically connected to the production tubing and provides the hydraulic connection to the telescoping joint and the pump sub. The pump sub is located parallel to the telescoping joint, and the pump sub is connected to an electric submersible pump string.

A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

A wellbore assembly includes a wellbore string configured to be disposed within a wellbore. The wellbore assembly also includes a float collar coupled to a downhole end of the wellbore string. The float collar includes a housing, a check valve, and a sleeve. The housing includes a fluid outlet. The housing defines a fluid port that extends through a wall of the housing. The check valve is disposed within the housing between the fluid port and the fluid outlet. The sleeve is coupled to the wall of the housing uphole of the check valve. The sleeve moves, based on pressure changes of the fluid in the float collar, with respect to the wall of the housing thereby either exposing the fluid port and opening a fluid pathway from the bore to an annulus of the wellbore, or covering the fluid port and blocking the fluid pathway.

A check valve assembly disposed within a pipe joint. The valve assembly is bounded by a pin end on one side and a liner tube on the other. In a first flow condition, a ball is forced away from the pin end and toward a stop member. The stop member has a geometry to allow fluid flow around the ball and through passageways within the stop when in the first flow condition. In a second flow condition, opposite the first flow condition, the ball is forced toward a tapered seat on the pin end, restricting fluid flow in the second flow condition.

A check valve assembly disposed within a pipe joint. The valve assembly is bounded by a pin end on one side and a liner tube on the other. In a first flow condition, a ball is forced away from the pin end and toward a stop member. The stop member has a geometry to allow fluid flow around the ball and through passageways within the stop when in the first flow condition. In a second flow condition, opposite the first flow condition, the ball is forced toward a tapered seat on the pin end, restricting fluid flow in the second flow condition.

A flow control assembly including a subassembly including an annular safety valve, a shroud, a bushing connecting the shroud to the subassembly at one of two opposing ends of the shroud, and another bushing connecting the shroud to the subassembly at the other of the two opposing ends of the shroud. The method for operating a hydrogen storage and production system including pumping hydrogen into the salt cavern for storage through a borehole and producing hydrogen from the salt cavern through the same borehole.

A flow control assembly including a subassembly including an annular safety valve, a shroud, a bushing connecting the shroud to the subassembly at one of two opposing ends of the shroud, and another bushing connecting the shroud to the subassembly at the other of the two opposing ends of the shroud. The method for operating a hydrogen storage and production system including pumping hydrogen into the salt cavern for storage through a borehole and producing hydrogen from the salt cavern through the same borehole.

Provided is a wellbore leg, a multilateral junction, and well system. The wellbore leg, in one aspect, includes a tubular having a fluid passageway extending there through, and an articulating structures located within the fluid passageway. In at least one aspect, the articulating structures includes a first portion, and a second portion, wherein the first portion and the second portion are coupled to one another and operable to rotate relative to one another.

Provided is a wellbore leg, a multilateral junction, and well system. The wellbore leg, in one aspect, includes a tubular having a fluid passageway extending there through, and an articulating structures located within the fluid passageway. In at least one aspect, the articulating structures includes a first portion, and a second portion, wherein the first portion and the second portion are coupled to one another and operable to rotate relative to one another.