An apparatus includes a gauge cutter, a lead impression block (LIB), a locking pin, and a locking device. The gauge cutter has a gauge cutter tubular body, a gauge cutter head, and an orifice. The LIB has an LIB body and an LIB head. The LIB is fixed in a first position within the orifice of the gauge cutter by being connected to an inner circumferential surface of the gauge cutter tubular body using a shear pin. The locking pin is disposed around the LIB body. The locking device is disposed around the inner circumferential surface of the gauge cutter tubular body and is configured to mate with the locking pin to hold the LIB in a second position within the gauge cutter. The second position includes a portion of the LIB body located within the orifice and the LIB head located outside of the orifice.

Downhole cutting tool positioning assemblies and methods to cut a tubular are presented. The assembly includes a drive screw, a drive nut coupled to the drive screw and configured to shift from a first position to a second position as the drive screw rotates in a first drive screw direction, a pressure piston configured to shift from a first position to a second position in response to force applied to the pressure piston, a chamber having a pressure fluid that is pressurized by the pressure piston as the pressure piston shifts from the first position towards the second position, a sleeve configured to slide from a first position towards a second position in response to pressure from the pressure fluid, and a latch key having a profile configured to shift radially to engage a tubular groove as the sleeve shifts from the first position towards the second position.

Downhole cutting tool positioning assemblies and methods to cut a tubular are presented. The assembly includes a drive screw, a drive nut coupled to the drive screw and configured to shift from a first position to a second position as the drive screw rotates in a first drive screw direction, a pressure piston configured to shift from a first position to a second position in response to force applied to the pressure piston, a chamber having a pressure fluid that is pressurized by the pressure piston as the pressure piston shifts from the first position towards the second position, a sleeve configured to slide from a first position towards a second position in response to pressure from the pressure fluid, and a latch key having a profile configured to shift radially to engage a tubular groove as the sleeve shifts from the first position towards the second position.

A method and apparatus to move an object in an open hole section of a wellbore. A bottom hole assembly including a downhole pulling tool and fishing device is described. The downhole pulling tool includes an open hole anchor to allow location of the downhole pulling tool in the open hole section of the wellbore so as to reduce the operating distance between the downhole pulling tool and the fishing device. An embodiment in which a cut section of tubular is removed from the open hole section is described. A casing cutter may also be located in the bottom hole assembly to cut the tubular on the same trip in the well as removing the cut section of tubular.

A method and apparatus to move an object in an open hole section of a wellbore. A bottom hole assembly including a downhole pulling tool and fishing device is described. The downhole pulling tool includes an open hole anchor to allow location of the downhole pulling tool in the open hole section of the wellbore so as to reduce the operating distance between the downhole pulling tool and the fishing device. An embodiment in which a cut section of tubular is removed from the open hole section is described. A casing cutter may also be located in the bottom hole assembly to cut the tubular on the same trip in the well as removing the cut section of tubular.

A casing removal system includes a flow diversion valve. The flow diversion valve includes a flow switch that engages an upper end of an inner casing. When the flow switch engages the upper end of the inner casing, the flow diversion valve opens and at least a portion of the fluid flow through the casing removal system exhausts to the annulus. The remaining fluid flow below the flow diversion valve is insufficient to operate a mud motor that drives a casing cutter. In other embodiments, when the flow switch is not engaged with the inner wall of casing, the flow diversion valve prevents fluid flow to components that are downhole of the valve and when the flow switch is engaged with the inner wall of casing, the flow diversion valve allows for fluid flow to components that are downhole of the valve.

A drilling assembly comprises a drill bit and a cutting assembly. The drilling assembly forms a longitudinal center axis. The drill bit and cutting assembly fastened to a rotatable spline drive assembly. The cutting assembly resiliently displaceable to the drill bit along the center axis such that in a first position the drill bit is surrounded by the cutting assembly, and in a second position a free end portion of the drill bit is projecting beyond the cutting assembly along the center axis. The cutting assembly comprises an endmill. The endmill comprises a central through hole complementary to the outer diameter of the drill bit. A method for cutting swarfs created by drilling, with an endmill, is described.

Systems and methods for drilling a geothermal well can include drilling a vertical borehole to a target location, drilling a plurality of lateral boreholes, each of which is connected to the vertical borehole, and can include generating a plurality of chambers in at least one of the plurality of lateral boreholes. The techniques can include drilling a plurality of passageways that each provide fluid communication between one of the plurality of chambers in a first lateral borehole and a second lateral borehole of the plurality of lateral boreholes. The techniques can form a fluid circuit for injecting a heating fluid such as water or brine and recovering hot water and steam using a single vertical borehole. The hot water and/or steam can be used to generate electrical power with a geothermal power facility.

A frac dart includes a body having an outer surface and an end including at least one opening. A cutter support is mounted at the end adjacent the at least one opening. A cutter is moveably mounted at the cutter support. A counter support is slideably mounted on the outer surface, and a counter is arranged between the counter support and the cutter support. The cutter is operable to sever a portion of the counter.

A frac dart includes a body having an outer surface and an end including at least one opening. A cutter support is mounted at the end adjacent the at least one opening. A cutter is moveably mounted at the cutter support. A counter support is slideably mounted on the outer surface, and a counter is arranged between the counter support and the cutter support. The cutter is operable to sever a portion of the counter.