Abstract: An apparatus and method is provided for locating joints in coiled tubing operations. The apparatus is adapted for running into a well on coiled tubing and for use during reverse circulating and fracturing operations. The apparatus having a central passageway for fluids, a collar locator module, a one-way valve coupled to the central passageway to allow for the flow of fluids in one direction but not the other, a port coupled to the central passageway to allow fluids to exit when the one-way valve is functioning, a movable cover module to cover the port to build up pressure in the central passageway, and a flow diverting module for permanently diverting the flow of fluids from the port to the central passageway.

Abstract: An apparatus and method is provided for locating joints in coiled tubing operations. The apparatus is adapted for running into a well on coiled tubing and for use during reverse circulating and fracturing operations. The apparatus having a central passageway for fluids, a collar locator module, a one-way valve coupled to the central passageway to allow for the flow of fluids in one direction but not the other, a port coupled to the central passageway to allow fluids to exit when the one-way valve is functioning, a movable cover module to cover the port to build up pressure in the central passageway, and a flow diverting module for permanently diverting the flow of fluids from the port to the central passageway.

Abstract: A well tool assembly interconnection method is provided. In a described embodiment, a continuous tubing string has connectors positioned corresponding to desired locations for tool assemblies in a well. The tubing string is wrapped on a reel and transported to a well. As the tubing string is deployed from the reel into the well, the tool assemblies are interconnected between the connectors.

Abstract: A well tool assembly interconnection method is provided. In a described embodiment, a continuous tubing string has connectors positioned corresponding to desired locations for tool assemblies in a well. The tubing string is wrapped on a reel and transported to a well. As the tubing string is deployed from the reel into the well, the tool assemblies are interconnected between the connectors.

Abstract: An apparatus and method is provided for locating joints in coiled tubing operations. The apparatus is adapted for running into a well on coiled tubing and for use during reverse circulating and fracturing operations. The apparatus having a central passageway for fluids, a collar locator module, a one-way valve coupled to the central passageway to allow for the flow of fluids in one direction but not the other, a port coupled to the central passageway to allow fluids to exit when the one-way valve is functioning, a movable cover module to cover the port to build up pressure in the central passageway, and a flow diverting module for permanently diverting the flow of fluids from the port to the central passageway.

Abstract: A well tool assembly interconnection method is provided. In a described embodiment, a continuous tubing string has connectors positioned corresponding to desired locations for tool assemblies in a well. The tubing string is wrapped on a reel and transported to a well. As the tubing string is deployed from the reel into the well, the tool assemblies are interconnected between the connectors.

Abstract: A wireless coiled tubing joint locator for locating joints or collars in a production tubing string. An electromagnetic coil assembly or giant magnetoresistive digital field sensor senses the increased mass of a pipe joint, and provides a signal to an electric circuit which generates a signal received by a pilot solenoid valve. The solenoid valve momentarily opens a pilot passageway which activates a piston to close a circulation port in the joint locator, resulting in an increase in a surface pressure reading observable by the operator. In one embodiment, a rupture disk is provided so that pressure cannot be applied to any downhole tool below the joint locator prematurely. A seat sleeve prevents premature communication of fluid to the rupture disk but can be opened by dropping a ball into the joint locator. A second embodiment may be used for either logging or washing operations or both. The electronic circuit can provide a selected one of a plurality of time delays.

Abstract: A wireless coiled tubing joint locator for locating joints or collars in a production tubing string. The joint locator is adapted for running into a well on coiled tubing, and other downhole tools may be connectable to the joint locator. An electromagnetic coil assembly senses the increased mass of a pipe joint, and provides a signal to an electric circuit which generates a momentary electric output signal received by a pilot solenoid valve. The solenoid valve momentarily opens a pilot passageway which activates a piston to close a circulation port in the joint locator. This closing of the circulation point results in an increase in a surface pressure reading observable by the operator. A rupture disk is provided so that pressure cannot be applied to any downhole tool below the joint locator prematurely, and a seat sleeve is provided to prevent premature communication of fluid to the rupture disk but can be opened at any time by dropping a ball into the joint locator.

Abstract: A ball drop tool, for dropping a ball to a ball seat located in a tool, or tool string therebelow. The ball drop tool has an upper end adapted to be connected to the lower end of the coiled tubing string. The ball drop tool includes a housing with a ball drop cage positioned therein. The ball drop cage has a rocker arm pivotally attached thereto. The rocker arm can be pivoted so that a lower end thereof extends radially inwardly into an opening and will hold a ball in the cage. The cage will move downwardly in the housing until the lower end of the rocker arm is retracted from the opening, which will allow the ball to pass downwardly through the ball drop housing so that it can be received in a ball seat in a tool therebelow.

Abstract: A heavy-duty logging and perforating cablehead for coiled tubing. The cablehead includes an upper and lower housing which are shearably connected by shear pins. An actuating piston is slidably disposed in the housing. When the piston is in a running position, the piston holds a lug in locking engagement with the upper and lower housings such that the shear pins cannot be sheared. When the piston is moved to a releasing position, the lugs are released so that the upper and lower housings may be separated, thereby shearing the shear pins. Actuation of the piston is accomplished by pumping fluid down the coiled tubing and through a flow path in the cablehead and by applying pressure to the piston.

Abstract: A coiled tubing drilling hydraulic disconnect for use in disconnecting a tool from a length of tubing or other tool string. The apparatus has an upper housing and a lower housing with a splined ring threadingly engaged with the lower housing. A spline in the splined ring engages a spline on the upper housing so that torque may be transmitted therebetween. Lugs are disposed through windows in the lower housing below the splines, and a bushing is disposed between the splined ring and the lugs. Relative rotation between the upper and lower housings causes the splined ring to tighten against the bushing and lugs, thereby eliminating play therebetween. A lug prop disposed in the upper housing may be hydraulically actuated so that the lugs may move to a disconnect position, thereby releasing the upper housing from the lower housing. Because the windows are disposed below the splines, no torque or bending are applied to the windows, and the windows and lugs are shaped to minimize stress concentrations.

Abstract: The apparatus and method for injecting coiled tubing downhole includes a connector member disposed on the end of the coiled tubing and supporting a downhole tool. A packer member is releasably connected to the connector member. The packer member includes a pack-off element and slips for releasably engaging the outer pipe string through which the coiled tubing is being injected. Seals are provided on the packer member for engaging the outer circumferential surface of the coiled tubing. A fluid passageway extends through the connector member for communicating the packer member with the coiled tubing. Fluid pressure is applied through the flow bore of the coiled tubing. The fluid pressure is applied through the fluid passageway to actuate an actuator member in the packer member to set the pack-off element and slips. Thus, upon actuating the packer member, the annulus formed by the coiled tubing and outer pipe string is closed.

Abstract: A resettable well stimulation tool is lowerable into a well bore on a length of tubing through which pressurized fluid may be forced into the tool to inflate a packer portion carried by the tool and then discharge a stimulation fluid into a portion of the well bore sealed off by the packer portion. During the inflation cycle of the tool pressurized fluid is forced downwardly into an annular tool body inflation chamber that communicates with an inflatable packer carried by the tool body. A perforated tube member coaxially carried in the inflation chamber serves to vertically distribute the inflation pressure along the length of the packer and assure its even inflation. In a straddle packer embodiment of the tool inflation and stimulation passages extend internally through the tool and are sealingly separated by an internal crossover structure, with the inflation passage being in communication with upper and lower packer members.

Abstract: The apparatus and method for injecting coiled tubing downhole includes a connector member disposed on the end of the coiled tubing and supporting a downhole tool. A packer member is releasably connected to the connector member. The packer member includes a pack-off element and slips for releasably engaging the outer pipe string through which the coiled tubing is being injected. Seals are provided on the packer member for engaging the outer circumferential surface of the coiled tubing. A fluid passageway extends through the connector member for communicating the packer member with the coiled tubing. Fluid pressure is applied through the flow bore of the coiled tubing. The fluid pressure is applied through the fluid passageway to actuate an actuator member in the packer member to set the pack-off element and slips. Thus, upon actuating the packer member, the annulus formed by the coiled tubing and outer pipe string is closed.

Abstract: The apparatus and method for injecting coiled tubing downhole includes a connector member disposed on the end of the coiled tubing and supporting a downhole tool. The connector member includes a dual check valve in the fluid passageway which allows fluid passage to actuate the packer member and closes the fluid passage after the connector member is disconnected from the packer member. The connector member may also include a valve member which allows circulation down the flow bore of the coiled tubing. The packer member includes a valve for the passage of well fluids between the packer member and coiled tubing.

Abstract: A well pipe string joint locator for attachment to the end of a length of coiled tubing and moved within the pipe string as the coiled tubing is lowered or raised therein is provided as well as methods of using the joint locator. The joint locator is comprised of an elongated tubular housing having a longitudinal fluid flow passageway therethrough and having at least one lateral port extending through a side thereof. Electronic means are disposed within the housing for detecting the increased mass of a pipe joint as said locator is moved through the joint and generating a momentary electric output signal in response thereto. Valve means are disposed within the housing responsive to the electric signal for momentarily opening or closing the lateral port of the housing to thereby create a surface detectible pressure drop or rise.

Abstract: A downhole inspection tool is attached to the lower end of a length of coiled tubing having an electrical/fiberoptic cable threaded through the center. The coiled tubing carries a flow of optically clear and/or acoustically homogeneous fluid from a supply of such fluid at the surface. The tool itself includes a cable head subassembly module attached to the lower end of the coiled tubing and terminates the electrical and optical conductors within the cable. An inspection module for producing an electrical signal indicative of downhole conditions is detachably connected to the lower end of the cable head assembly module. An outer flow tube is mechanically connected to the inspection module and surrounds both of the modules to define an annular space therebetween.

Abstract: Method of conveying a downhole tool by a coiled tubing unit into a wellbore having a wellhead, and in which the downhole tool is to be communicatively linked to surface equipment by way of an electrical and/or optical cable. The method includes providing a coiled tubing unit, providing a downhole tool that is attachable to the coiled tubing directly, or indirectly attachable to the tubing by way of a provided cablehead, attaching one end of the cable to a cable connector that is in electrical and/or optical communication with the downhole tool, providing and installing a Y-connector to the wellhead of the wellhead of the well bore, the Y-connector having a branch that sealingly accommodates the coiled tubing therethrough, and a branch that sealingly accommodates the cable therethrough. The method further includes tensioning the cable as the cable and the tubing is simultaneously conveyed into and out of the well bore by way of respective branches of the Y-connector.

Abstract: The present apparatus describes a mechanism used with a lubricatior used for straightening tubing inserted into a well during service operations. The injector incorporates multiple drive chains which carry gripping blocks or mechanisms for engaging the tubing and which provide direct measurement of the travel of the tubing as it is inserted. As tubing is inserted, a sprocket is rotated on engagement with the drive chain and it in turn rotates a shaft supporting a smaller sprocket engaged by a link chain with another sprocket. The various sprockets have selected teeth ratios to provide the requisite proportionate scaling of the system. The last sprocket drives a pulse generator which forms pulses proportionate to tubing insertion into the well.