A system for connecting a drill bit and pipe puller to a drill string. The system includes a downhole tool having an internal cavity and a through-hole in its wall. A coupler may be slidingly received in the cavity and connected using one or more fasteners which interconnect a groove in the coupler to the wall of the downhole tool. Fasteners used may be screws or bolts interconnecting the wall of the tool with radial holes in the coupler. Alternatively, bolts may interconnect the wall with a circumferential groove on the coupler. A drill bit may be threaded into the coupler. The coupler allows drill bits and other tools to be connected and disconnected from a downhole tool without unthreading the drill bit.

An assembly adapted to be disposed within an oil or gas wellbore and including first and second completion joints, each including a base pipe, a shunt tube disposed along the base pipe, and a tubular outer shroud disposed about respective portions of the shunt tube and the base pipe; a jumper tube coupling the shunt tube of the first completion joint to the shunt tube of the second completion joint; and a tubular sliding shroud disposed about at least one of the first and second completion joints and adapted to slide longitudinally to a run-in position, in which the tubular sliding shroud is disposed about the jumper tube and respective portions of the first and second completion joints, thereby covering the jumper tube. A method and apparatus are also provided.

An assembly adapted to be disposed within an oil or gas wellbore and including first and second completion joints, each including a base pipe, a shunt tube disposed along the base pipe, and a tubular outer shroud disposed about respective portions of the shunt tube and the base pipe; a jumper tube coupling the shunt tube of the first completion joint to the shunt tube of the second completion joint; and a tubular sliding shroud disposed about at least one of the first and second completion joints and adapted to slide longitudinally to a run-in position, in which the tubular sliding shroud is disposed about the jumper tube and respective portions of the first and second completion joints, thereby covering the jumper tube. A method and apparatus are also provided.

The present invention relates to a liquid evacuation device for an extraction well. The device comprises a tank presenting a liquid accumulation area. The tank is connected to a gas evacuation tubing. An insulant limits a flow of fluid between a wall of the tank and a wall of the well, from a first space formed between the insulant and the well bottom to a second space formed between the insulant and the well head. A first opening on the tank enables circulation of a gas-liquid mixture from said first space to a third space formed in the gas evacuation tubing. A second opening on the tank enables circulation of fluid from said second space to the liquid accumulation area. The first opening is made between the liquid accumulation area and the connection to the evacuation tubing.

Provided is a multilateral junction (MLT), a well system, and a method for forming a well system. The MLT, in one aspect, includes a y-block having a housing with a single first bore and second and third bores extending therein, the second and third bores defining second and third centerlines. The MLT, in this aspect, further includes a mainbore leg having a first mainbore leg end coupled to the second bore and a second opposing mainbore leg end, and a lateral bore leg having a first lateral bore leg end coupled to the third bore and a second opposing lateral bore leg end. In this aspect, the mainbore leg and the lateral bore leg are twisted with respect to the second and third bore such that a first plane taken through centerlines of the second opposing mainbore leg end and the second opposing lateral bore leg end is angled.

Provided is a multilateral junction (MLT), a well system, and a method for forming a well system. The MLT, in one aspect, includes a y-block having a housing with a single first bore and second and third bores extending therein, the second and third bores defining second and third centerlines. The MLT, in this aspect, further includes a mainbore leg having a first mainbore leg end coupled to the second bore and a second opposing mainbore leg end, and a lateral bore leg having a first lateral bore leg end coupled to the third bore and a second opposing lateral bore leg end. In this aspect, the mainbore leg and the lateral bore leg are twisted with respect to the second and third bore such that a first plane taken through centerlines of the second opposing mainbore leg end and the second opposing lateral bore leg end is angled.

One illustrative production/annulus bore stab disclosed herein includes a one-piece body that comprises a first cylindrical outer surface and a second cylindrical outer surface and a plurality of individual fluid flow paths defined entirely within the one-piece body. In this illustrative example, each of the individual fluid flow paths is fluidly isolated from one another and each of the fluid flow paths comprise a first inlet/outlet at a first end of the fluid flow path that is positioned in the first cylindrical outer surface and a second inlet/outlet at a second end of the fluid flow path that is positioned in the second cylindrical outer surface.

One illustrative production/annulus bore stab disclosed herein includes a one-piece body that comprises a first cylindrical outer surface and a second cylindrical outer surface and a plurality of individual fluid flow paths defined entirely within the one-piece body. In this illustrative example, each of the individual fluid flow paths is fluidly isolated from one another and each of the fluid flow paths comprise a first inlet/outlet at a first end of the fluid flow path that is positioned in the first cylindrical outer surface and a second inlet/outlet at a second end of the fluid flow path that is positioned in the second cylindrical outer surface.

A drill bit includes a bit body with high and low fluid pressure bodies. The low-pressure bit body includes a fixed cutting structure, and the high-pressure bit body includes at least one high-pressure fluid channel and nozzle capable of withstanding fluid pressures greater than 40 kpsi (276 MPa). A bottomhole assembly includes a drill bit with a bit body having fixed cutter and fluid jetting portions. Low and high-pressure channels in the bit body exit in the fixed cutter and fluid jetting portions. A high-pressure nozzle is coupled to the fluid jetting portion and the high-pressure fluid channel, and a plurality of fixed cutting elements are coupled to the fixed cutter portion. A pressure intensifier is coupled to the drill bit and is configured to increase a pressure of a fluid supplied to the high-pressure fluid channel in the bit body.

A drill bit includes a bit body with high and low fluid pressure bodies. The low-pressure bit body includes a fixed cutting structure, and the high-pressure bit body includes at least one high-pressure fluid channel and nozzle capable of withstanding fluid pressures greater than 40 kpsi (276 MPa). A bottomhole assembly includes a drill bit with a bit body having fixed cutter and fluid jetting portions. Low and high-pressure channels in the bit body exit in the fixed cutter and fluid jetting portions. A high-pressure nozzle is coupled to the fluid jetting portion and the high-pressure fluid channel, and a plurality of fixed cutting elements are coupled to the fixed cutter portion. A pressure intensifier is coupled to the drill bit and is configured to increase a pressure of a fluid supplied to the high-pressure fluid channel in the bit body.