Abstract: A method of monitoring a coiled tubing operation includes positioning a bottom hole assembly (BHA) connected to a coiled tubing string within a horizontal wellbore. The method includes monitoring a plurality of sensors connected to the BHA via a communication line positioned within the coiled tubing string and determining an optimal injection speed of the coiled tubing string by monitoring the sensors in real-time. The injection speed of the coiled tubing may be changed based on the real-time determination of the optimal injection speed. The sensors may be monitored in real-time to determine an optimal amount of lubricant to be injected into a wellbore or whether the coiled tubing string is forming a helix. The BHA may include a tractor or a vibratory tool to aid in the movement of the BHA along a horizontal wellbore. The communication line may be used to power the sensors, tractor, and vibratory tool.

Abstract: A system and method for splicing a non-spoolable tool anywhere along a coiled tubing string. A removable tubing section may be connected along a coiled tubing string by two spoolable connectors. The coiled tubing string may be unspooled from a reel until the removable tubing section and connectors are positioned within a work window. The removable tubing section may be disconnected from the tubing string through the work window and a tool may be connected to the coiled tubing string via the two connectors. The tool may then be positioned within a wellbore by insertion of the coiled tubing string. The tool may aid in the insertion of the coiled tubing string into the wellbore. A portion of the wellhead may be disconnected and raised to expose the connectors to permit the removal of the removable tubing section and the connection of a non-spoolable tool.

Abstract: A method of monitoring a coiled tubing operation includes positioning a bottom hole assembly (BHA) connected to a coiled tubing string within a horizontal wellbore. The method includes monitoring a plurality of sensors connected to the BHA via a communication line positioned within the coiled tubing string and determining an optimal injection speed of the coiled tubing string by monitoring the sensors in real-time. The injection speed of the coiled tubing may be changed based on the real-time determination of the optimal injection speed. The sensors may be monitored in real-time to determine an optimal amount of lubricant to be injected into a wellbore or whether the coiled tubing string is forming a helix. The BHA may include a tractor or a vibratory tool to aid in the movement of the BHA along a horizontal wellbore. The communication line may be used to power the sensors, tractor, and vibratory tool.

Abstract: A wellbore completion is disclosed. The wellbore completion comprises a casing assembly comprising a plurality of casing lengths. At least one collar is positioned so as to couple the casing lengths. The at least one collar comprises a tubular body having an inner flow path and at least one fracture port configured to provide fluid communication between an outer surface of the collar and the inner flow path. A length of coiled tubing can be positioned in the casing assembly. The coiled tubing comprises an inner flow path, wherein an annulus is formed between the coiled tubing and the casing assembly. A bottom hole assembly is coupled to the coiled tubing. The bottom hole assembly comprises a fracturing aperture configured to provide fluid communication between the inner flow path of the coiled tubing and the annulus. A packer can be positioned to allow contact with the at least one collar when the packer is expanded.

Abstract: A system and method for splicing a non-spoolable tool anywhere along a coiled tubing string. A removable tubing section may be connected along a coiled tubing string by two spoolable connectors. The coiled tubing string may be unspooled from a reel until the removable tubing section and connectors are positioned within a work window. The removable tubing section may be disconnected from the tubing string through the work window and a tool may be connected to the coiled tubing string via the two connectors. The tool may then be positioned within a wellbore by insertion of the coiled tubing string. The tool may aid in the insertion of the coiled tubing string into the wellbore. A portion of the wellhead may be disconnected and raised to expose the connectors to permit the removal of the removable tubing section and the connection of a non-spoolable tool.

Abstract: The present disclosure is directed to a cutting dart. The cutting dart comprises a dart body including a first pathway. The first pathway is configured to redirect cutting fluid flowing through a coiled tubing so that the cutting fluid flows radially to impinge against an inner surface of the coiled tubing. A seal is positioned around an outer circumference of the dart body. The present disclosure is also directed to an anchor dart. The anchor dart comprises a dart body and a swellable elastomer positioned around an outer circumference of the dart body. Methods of employing the cutting dart and anchor dart are also disclosed.

Abstract: A wellbore completion is disclosed. The wellbore completion comprises a casing assembly comprising a plurality of casing lengths. At least one collar is positioned so as to couple the casing lengths. The at least one collar comprises a tubular body having an inner flow path and at least one fracture port configured to provide fluid communication between an outer surface of the collar and the inner flow path. A length of coiled tubing can be positioned in the casing assembly. The coiled tubing comprises an inner flow path, wherein an annulus is formed between the coiled tubing and the casing assembly. A bottom hole assembly is coupled to the coiled tubing. The bottom hole assembly comprises a fracturing aperture configured to provide fluid communication between the inner flow path of the coiled tubing and the annulus. A packer can be positioned to allow contact with the at least one collar when the packer is expanded.

Abstract: The present disclosure is directed to a cutting dart. The cutting dart comprises a dart body including a first pathway. The first pathway is configured to redirect cutting fluid flowing through a coiled tubing so that the cutting fluid flows radially to impinge against an inner surface of the coiled tubing. A seal is positioned around an outer circumference of the dart body. The present disclosure is also directed to an anchor dart. The anchor dart comprises a dart body and a swellable elastomer positioned around an outer circumference of the dart body. Methods of employing the cutting dart and anchor dart are also disclosed.

Abstract: In some embodiments, a method of allowing a subterranean formation to be fractured from an open hole well bore section includes providing a removable coating across substantially the entire surface of the wall of the well bore section, selectively removing the coating at a desired first fracture initiation location and allowing the first fracture to be formed in the vicinity of the desired first fracture initiation location.

Abstract: In some embodiments, a method of allowing a subterranean formation to be fractured from an open hole well bore section includes providing a removable coating across substantially the entire surface of the wall of the well bore section, selectively removing the coating at a desired first fracture initiation location and allowing the first fracture to be formed in the vicinity of the desired first fracture initiation location.

Abstract: Apparatus and methods for removing sand and/or other fill material located in a wellbore ahead of a coiled tubing tractor and displacing the material behind the tractor. More particularly, the apparatus and methods allow a coiled tubing tractor to drive forward in a wellbore by removing fill material in front of the tractor thereby allowing the wheels or traction pads of the tractor to remain in contact with the wellbore.

Abstract: A dual tubing coiled tubing string, including methods of assembly, that includes an inner tubing sealed within at least an upper portion of an outer tubing.

Abstract: Method and Apparatus for gravel packing, cleaning and lifting wells, including through tubing methods, circulating well fluids through a coiled tubing string having a leak protection barrier operable for at least a portion of the string passing above a wellhead and employing a circulating and release sub.

Abstract: Method and apparatus for performing well operations, such as measuring or forming or testing or treating or the like, and combinations of the above operations, including the use of coiled-in-coiled tubing (CCT) connected to a bottomhole assembly package (BHA), such that the assembly is in communication with both fluid conduits (80 and 82) defined by the coiled-in-coiled tubing.

Abstract: Method and apparatus for removing drill cuttings from a deviated wellbore drilled with coiled tubing, and more particularly method and apparatus for removing "cuttings beds" from a significantly horizontal wellbore drilled with a downhole motor by creating flow of fluid in the wellbore at a critical flow rate, above a flow rate range designed for the drilling.

Abstract: A safeguarded method and apparatus for providing fluid communication with coiled tubing, said coiled tubing comprising more particularly coiled-in-coiled tubing, having a inner tube and an outer tube, and including multicentric coiled-in-coiled tubing and its method of assembly, the safeguarded method having particular applicability to drill stem testing.

Abstract: A method of testing for leaks in tubing and tube joints comprises placing within the tube to be tested a tool having spaced seals so that the seals are arranged on opposite sides of the joint to be tested in engagement at a constant pressure against the internal surface of the tubing. A search fluid such as 1 to 2% helium in air is passed through the tool under pressure and then out from the tool into the annular space between the outside surface of the tool and the inside surface of the tubing between the two seals. The presence of any helium is detected by means of a helium detector for example a mass spectrometer which has a probe extending to a gas trap surrounding the joint to be tested.