A downhole apparatus including a sleeve, a tool string, a plug, a means for setting the plug wherein an upper portion of the sleeve is connectable to a lower portion of the tool string, and a lower portion of the sleeve is arranged to receive the plug and the means for setting the plug. A method for using the downhole apparatus (1) is disclosed.

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 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 method of plugging a hydrocarbon well includes deploying a downhole tool to remove at least a portion of a casing at a section of well to be plugged. Deploying a blocking device downhole to block a bottom of the section of well to be plugged. Deploying a plugging material downhole onto the blocking device to fill an area to be plugged. Deploying an exothermic fluid downhole, wherein activation of the exothermic material liquefies the plugging material. Allowing the plugging material and the exothermic fluid to solidify form a cast-in-place plug that fills the section of well to be plugged.

A method of plugging a hydrocarbon well includes deploying a downhole tool to remove at least a portion of a casing at a section of well to be plugged. Deploying a blocking device downhole to block a bottom of the section of well to be plugged. Deploying a plugging material downhole onto the blocking device to fill an area to be plugged. Deploying an exothermic fluid downhole, wherein activation of the exothermic material liquefies the plugging material. Allowing the plugging material and the exothermic fluid to solidify form a cast-in-place plug that fills the section of well to be plugged.

A drilling assembly (1) for making a passage in an object (2) within a petroleum well (8). The drilling assembly (1) comprises a drill bit assembly (3), a cutting assembly (4), and both assemblies (3, 4) are fastened to a rotatable drive assembly (5), the drill bit assembly (3) comprises a drill bit (31); the cutting assembly (4) comprises a hole saw assembly (42); the cutting assembly (4) is resiliently displaceable to the drill bit assembly (3). The drilling assembly (1) comprises a displaceable membrane (6) within the tubular body (41). The membrane (6) divides an interior (43) of the tubular body (41) in a receiving compartment (69) and an inner compartment (60).

A drilling assembly (1) for making a passage in an object (2) within a petroleum well (8). The drilling assembly (1) comprises a drill bit assembly (3), a cutting assembly (4), and both assemblies (3, 4) are fastened to a rotatable drive assembly (5), the drill bit assembly (3) comprises a drill bit (31); the cutting assembly (4) comprises a hole saw assembly (42); the cutting assembly (4) is resiliently displaceable to the drill bit assembly (3). The drilling assembly (1) comprises a displaceable membrane (6) within the tubular body (41). The membrane (6) divides an interior (43) of the tubular body (41) in a receiving compartment (69) and an inner compartment (60).

Techniques for removing a tubular from a wellbore include running a downhole tool on a downhole conveyance into a wellbore formed from a terranean surface into a subterranean formation; activating a piston sub-assembly to repeatedly move pistons to contact a portion of a casing installed in the wellbore to at least de-bond a cement layer installed between the portion of the casing and the subterranean formation from the portion of the casing; activating a cutting sub-assembly to move a cutting blade to cut through the portion of the casing adjacent the de-bonded portion of the cement layer; activating a hanger sub-assembly to move a set of slips into contacting engagement with the cut portion of the casing; and running the downhole tool on the downhole conveyance out of the wellbore with the cut portion of the casing engaged with the set of slips.

A bottom hole assembly comprising a downhole tool known as a cutting tool is provided for use within a subterranean well for severing tubulars. The cutting tool comprises a fluid source, a gas-driven rotatable motor and a cutting head including one or more cutters. The fluid source supplies pressurized fluid and thereby energy to the gas-driven rotatable motor which is disposed to generate thrust to set the gas-driven rotatable motor in motion. The cutting head is coupled to the gas-driven rotatable motor and rotates while cutting the tubular. The cutting tool can be deployed in a subterranean well by a variety of deployment methods, and the pressurized fluid may be supplied from a surface system, generated inside the cutting tool or bottom hole assembly, or input within the cutting tool or bottom hole assembly prior to deployment.

The invention further relates to associated methods.

A well tool for milling a tubular includes a well tubing disposed in a wellbore and including a circulation fluid pathway through an interior of the well tubing, a first milling tool coupled to the well tubing at a first longitudinal end of the well tubing, a second milling tool coupled to the well tubing at a location longitudinally uphole from the first milling tool, and a third milling tool coupled to the well tubing at a location longitudinally uphole from the second milling tool. Each of the milling tools include a mill bit and a circulation sub fluidly connected to the circulation fluid pathway. The first milling tool mills a first portion of the tubular, the second milling tool mills a second portion of the tubular, and the third milling tool mills a third portion of the tubular.