A new system for and a method of deploying a heat exchanger pipe. A bore hole is drilled from an access ditch location to a terminal ditch location using a piloted drill head powered via an umbilical attached to the piloted drill head. A casing is attached to the piloted drill head and disposed about the umbilical into the bore hole from the access ditch location to the terminal ditch location. At the terminal ditch location, the piloted drill head is removed from the casing and the umbilical and a heat exchanger pipe is attached to the umbilical. The umbilical is withdrawn from within the casing deployed in the bore hole to pull the heat exchanger pipe into the casing. The casing is then withdrawn from the bore hole leaving the heat exchanger pipe in the bore hole.

A new system for and a method of deploying a heat exchanger pipe. A bore hole is drilled from an access ditch location to a terminal ditch location using a piloted drill head powered via an umbilical attached to the piloted drill head. A casing is attached to the piloted drill head and disposed about the umbilical into the bore hole from the access ditch location to the terminal ditch location. At the terminal ditch location, the piloted drill head is removed from the casing and the umbilical and a heat exchanger pipe is attached to the umbilical. The umbilical is withdrawn from within the casing deployed in the bore hole to pull the heat exchanger pipe into the casing. The casing is then withdrawn from the bore hole leaving the heat exchanger pipe in the bore hole.

A flow-off telemetry system and method of communicating information from a downhole location in a borehole to a surface location while fluid circulation is off. A string is conveyed in the wellbore to define an inner bore and an annulus. During a flow-off condition, an inner bore sealing element closes the inner bore to create a first standing column of fluid in the inner bore, and an annulus sealing element closes the annulus to form a second standing column of fluid in the annulus. A bypass valve in the string at a downhole location between the first standing column of fluid and the second standing column of fluid is activated to generate a pressure pulse including information for performing an action. The pressure pulse is received at a pressure sensor at the surface location and a controller performs an action in response to the information in the pressure pulse.

A method of electrically logging a section of a wellbore includes circulating an oil-based wellbore fluid comprising a conductive carbon material therein, the oil-based wellbore fluid having a conductivity of at most 0.01 S/m when measured at 20 kHz, within the wellbore while drilling the wellbore with a drill bit on a drill string; applying electrical current from a logging tool on the drill string above the drill bit; and collecting an electrical log of the portion of the wellbore that has had electrical current applied thereto.

A method of electrically logging a section of a wellbore includes circulating an oil-based wellbore fluid comprising a conductive carbon material therein, the oil-based wellbore fluid having a conductivity of at most 0.01 S/m when measured at 20 kHz, within the wellbore while drilling the wellbore with a drill bit on a drill string; applying electrical current from a logging tool on the drill string above the drill bit; and collecting an electrical log of the portion of the wellbore that has had electrical current applied thereto.

Arrangement of a ground drilling device for the pushing or pulling introduction of a drill string into the ground, wherein the arrangement has a frame and a carriage which can be moved back and forth relative to the frame with a translatory movement, wherein at least one rolling element is provided, which is configured to roll during the translatory movement of the carriage, and a conversion device is provided, which is connected to the rolling element and is configured to convert the rotary movement of the rolling element into a rotary movement of the drill string.

A method of formulating an oil-based wellbore fluid, the method comprising adding at least a plurality of conductive carbon black agglomerates or pellets having an average size of at least 500 μm to an oleaginous base fluid, and applying energy to the oil-based wellbore fluid to disperse the plurality of conductive carbon black agglomerates or pellets into the oleaginous base fluid as finer particles than the agglomerates or pellets.

A method of formulating an oil-based wellbore fluid, the method comprising adding at least a plurality of conductive carbon black agglomerates or pellets having an average size of at least 500 μm to an oleaginous base fluid, and applying energy to the oil-based wellbore fluid to disperse the plurality of conductive carbon black agglomerates or pellets into the oleaginous base fluid as finer particles than the agglomerates or pellets.

Provided is a method for selecting one of a plurality of convergence paths that may be drilled by a bottom hole assembly (BHA) comprising identifying, by a computer system, a plurality of geometric convergence paths, wherein each of the geometric convergence paths provides a convergence solution from a defined bottom hole assembly (BHA) location to a target drilling path of a well plan. An offset distance is calculated for drilling by the BHA each of the geometric convergence paths connecting the BHA location to the target drilling path. A drill path curvature associated with drilling each of the geometric convergence paths by the BHA is determined by the computer system. A time required for drilling each of the geometric convergence paths by the BHA is determined by the computer system. An optimal geometric convergence path of the plurality of geometric convergence paths is determined responsive to the offset distance for drilling each of the geometric convergence paths, the drill path curvature associated with each of the geometric convergence paths and the time required for drilling each of the geometric convergence paths. The determined optimal geometric convergence path is fed to a controller associated with a display of a drilling rig and used to control the display of the drilling rig to display the determined optimal geometric convergence path.

Provided is a method for selecting one of a plurality of convergence paths that may be drilled by a bottom hole assembly (BHA) comprising identifying, by a computer system, a plurality of geometric convergence paths, wherein each of the geometric convergence paths provides a convergence solution from a defined bottom hole assembly (BHA) location to a target drilling path of a well plan. An offset distance is calculated for drilling by the BHA each of the geometric convergence paths connecting the BHA location to the target drilling path. A drill path curvature associated with drilling each of the geometric convergence paths by the BHA is determined by the computer system. A time required for drilling each of the geometric convergence paths by the BHA is determined by the computer system. An optimal geometric convergence path of the plurality of geometric convergence paths is determined responsive to the offset distance for drilling each of the geometric convergence paths, the drill path curvature associated with each of the geometric convergence paths and the time required for drilling each of the geometric convergence paths. The determined optimal geometric convergence path is fed to a controller associated with a display of a drilling rig and used to control the display of the drilling rig to display the determined optimal geometric convergence path.