Abstract: A compression indication tool can include a flow passage and a valve that in a closed configuration prevents fluid communication between the flow passage and an exterior of the tool, and in an open configuration permits fluid communication between the flow passage and the exterior of the tool. The valve is opened in response to application of a predetermined longitudinal compressive load to the compression indication tool. A method can include connecting a compression indication tool in a tool string, the tool including a valve that prevents fluid communication between an interior flow passage and an exterior of the tool, deploying the tool string into the well, and applying a predetermined longitudinal compressive load to the tool string, thereby opening the valve to permit fluid communication between the interior flow passage and the exterior of the tool.

Abstract: A coiled tubing system can include a reel, tubing wound onto the reel, and a roller positioned adjacent the reel, the roller contacting only an outer wrap of the tubing on the reel. A method of operating a coiled tubing system can include mounting a retaining roller assembly adjacent a reel, the retaining roller assembly including a roller having beveled ends, and winding a coiled tubing onto the reel, one of the beveled ends contacting the coiled tubing as the coiled tubing transitions between wraps on the reel. Another coiled tubing system can include a reel, tubing wound onto the reel, and a roller positioned adjacent the reel, the roller having a bevel formed on each end of the roller.

Abstract: A progressive cavity assembly can include a stator surrounding a rotor, the stator including a tubular housing and a stator section having a helical stator profile formed therein. A material between the stator section and the housing secures the stator section in the housing, and the material abuts a face of the stator section configured to prevent rotation of the stator section relative to the material. A method of producing a progressive cavity assembly can include providing a stator section having a helical stator profile formed therein, positioning the stator section in a tubular housing, centralizing the stator section in the housing, and injecting a material into a gap between an interior surface of the housing and an exterior surface of the stator section, thereby securing the stator section in the housing.

Abstract: A plug deployment tool can include a piston to displace plugging devices out of an outer housing assembly, the piston including four piston areas, one piston area being in fluid communication with a fluid chamber to be pressurized by ignition of a power charge, two piston areas being in fluid communication with an exterior of the plug deployment tool, and the other piston area being in fluid communication with an atmospheric chamber. Another plug deployment tool can include a piston including a piston area in fluid communication with a fluid chamber, and a valve that selectively prevents and permits fluid communication between the fluid chamber and an exterior of the plug deployment tool. A method of deploying plugging devices can include increasing fluid pressure applied to a piston area of a piston, thereby axially displacing the piston and discharging the plugging devices from the outer housing assembly.

Abstract: A method for displacing a tubular string in a wellbore can include axially vibrating the tubular string at a surface location, and reducing friction between the tubular string and the wellbore due to the axially vibrating. The axial vibration may be imparted by operation of an injector assembly. The axial vibration may be imparted by operation of a vibration tool connected between the injector assembly and a wellhead or a support structure that suspends the injector assembly. The axial vibration may be imparted by varying a flow rate of fluid into the tubular string.

Abstract: A method for displacing a tubular string in a wellbore can include axially vibrating the tubular string at a surface location, and reducing friction between the tubular string and the wellbore due to the axially vibrating. The axial vibration may be imparted by operation of an injector assembly. The axial vibration may be imparted by operation of a vibration tool connected between the injector assembly and a wellhead or a support structure that suspends the injector assembly. The axial vibration may be imparted by varying a flow rate of fluid into the tubular string.

Abstract: A system for use with a subterranean well can include a tubular string deployed in the well, at least one downhole tractor connected in the tubular string, and at least one downhole vibratory tool connected in the tubular string. Another system can include a tubular string deployed in a well, and at least one of the group consisting of multiple downhole tractors and multiple downhole vibratory tools connected in the tubular string. A compliance tool can be connected between a downhole tractor and a downhole vibratory tool connected in the tubular string.

Abstract: A disclosed system can include a flow modulation system at a surface location configured to receive fluid returned from a wellbore, the flow modulation system periodically varying a flow rate of the fluid returned from the wellbore. A method of advancing a tubular string can include pumping fluid through the tubular string and into a wellbore, returning the fluid to a surface location, and flowing the returned fluid through a time-varying flow restrictor at the surface location, thereby producing fluctuations in a flow rate of the returned fluid. Another system can include a pump connected to an annulus, a flow rate of fluid pumped into the annulus at a surface location is varied to thereby produce vibration of the tubular string. Another method can include varying a flow rate of fluid pumped into an annulus as a tubular string is advanced in a well, thereby vibrating the tubular string.

Abstract: A method can include deploying a tubular string into a perforated section of a wellbore, and introducing a diverting agent into a fluid flow in an annulus surrounding the tubular string, the diverting agent blocking the fluid flow through a set of perforations in the perforated section, thereby increasing a flow rate of the fluid flow in the annulus surrounding the tubular string and advancing the tubular string through the wellbore. Another method can include deploying a tubular string into a perforated section of a wellbore, the perforated section including multiple sets of perforations, a first set of the perforations being positioned uphole of a second set of the perforations, and blocking the first set of the perforations, thereby increasing a flow rate of fluid flow in an annulus surrounding the tubular string and advancing the tubular string through the wellbore.

Abstract: A method for use with a subterranean well can include deploying a plugging device and anchor into the well, conveying the anchor into a perforation and blocking fluid flow through the perforation with the plugging device. A system for use with a subterranean well can include a plugging device configured to engage and block fluid flow through a perforation in the well, and an anchor attached to the plugging device, the anchor being configured to grip an interior surface of the perforation.

Abstract: A fluid pump can include a tubular housing and multiple stator sections. Each of the stator sections has a helical stator profile formed therein. Deformation of the housing secures each respective stator section in the housing. A method of producing a fluid pump can include securing multiple stator sections to each other, each of the stator sections having a stator profile formed therein, and securing the stator sections in a tubular housing. The securing steps can be performed without any welding. The step of the securing the stator sections in the housing can include deforming the housing toward the stator sections.

Abstract: A fluid pump can include a tubular housing and multiple stator sections. Each of the stator sections has a helical stator profile formed therein. Deformation of the housing secures each respective stator section in the housing. A method of producing a fluid pump can include securing multiple stator sections to each other, each of the stator sections having a stator profile formed therein, and securing the stator sections in a tubular housing. The securing steps can be performed without any welding. The step of the securing the stator sections in the housing can include deforming the housing toward the stator sections.

Abstract: A downhole fluid motor can include a tubular housing and multiple stator sections. Each of the stator sections has a helical stator profile formed therein. Deformation of the housing secures each respective stator section in the housing. A method of producing a downhole fluid motor can include securing multiple stator sections to each other, each of the stator sections having a stator profile formed therein, and securing the stator sections in a tubular housing. The securing steps can be performed without any welding. The step of the securing the stator sections in the housing can include deforming the housing toward the stator sections.

Abstract: A progressive cavity assembly can include a stator having a tubular housing and a stator section having a helical stator profile formed therein. At least one deformation of the housing secures the stator section in the housing. A method of producing a progressive cavity assembly can include providing a stator section having a stator profile formed therein, and securing the stator section in a tubular housing. The step of securing the stator section in the housing can be performed without any welding. The step of securing the stator section in the housing can include deforming the housing toward the stator section.

Abstract: A well rig can include a mast, and multiple guide assemblies distributed along the mast. The guide assemblies are configured to laterally support a tubular string. A method of operating a well rig can include mounting multiple guide assemblies spaced apart along a length of a mast of the well rig, and actuating each of the guide assemblies between open and closed configurations. In the open configuration the guide assembly does not laterally support a tubular string, and in the closed configuration the guide assembly laterally supports the tubular string. Another method can include mounting multiple guide assemblies spaced apart along a length of a mast of a well rig, and displacing a top drive along the mast. The guide assemblies open in succession as the top drive descends along the mast, and the guide assemblies close in succession as the top drive ascends along the mast.

Abstract: A well rig can include a mast, and a strut assembly connected to the mast for transmitting a compressive load between the mast and a wellhead assembly, the strut assembly including an anchor that connects to an upper flange of the wellhead assembly. A method of aligning a well rig with a wellhead assembly can include raising a mast of the well rig, and deploying a strut assembly, thereby positioning an anchor relative to the mast. Another well rig can include a mast, and a strut assembly connected to the mast and including struts that transmit a compressive load between the mast and a wellhead assembly, the strut assembly further including an anchor that connects to the wellhead assembly, and the anchor including a rotatable flange body.

Abstract: A mobile well rig can include a mast, an anchor that connects to a flange of a wellhead assembly, and a tensile member that transfers tensile loads between the wellhead assembly and the mast. A method of securing a mobile well rig to a wellhead assembly can include connecting an anchor to the wellhead assembly, connecting a tensile member to the anchor, and connecting the tensile member to a mast of the mobile well rig. A securement system can include an anchor secured to a wellhead assembly, a tensile member that transfers a tensile load between the wellhead assembly and a mast of a mobile well rig, and a strut that transfers a compressive load between the wellhead assembly and the mast.

Abstract: A method of deploying plugging devices can include conveying a bottom hole assembly into a well, the bottom hole assembly comprising a plug deployment tool, and actuating the plug deployment tool, thereby dispensing at least one of the plugging devices from an interior of the plug deployment tool. A plug deployment tool can include a first chamber, a valve that isolates the first chamber from a second chamber, multiple plugging devices contained in an outer housing, and a piston that displaces one or more of the plugging devices out of the outer housing in response to the valve being opened. The second chamber can be disposed in the piston and can displace with the piston in response to the valve being opened.

Abstract: A method for displacing a tubular string in a wellbore can include axially vibrating the tubular string at a surface location, and reducing friction between the tubular string and the wellbore due to the axially vibrating. The axial vibration may be imparted by operation of an injector assembly. The axial vibration may be imparted by operation of a vibration tool connected between the injector assembly and a wellhead or a support structure that suspends the injector assembly. The axial vibration may be imparted by varying a flow rate of fluid into the tubular string.

Abstract: A method of deploying a plug in a subterranean well can include positioning a tool string in the well, the tool string including a plug release tool and a well tool, then releasing the plug from the plug release tool, and then operating the well tool in response to the releasing the plug. A plug release tool for use in a subterranean well can include an outer housing, and an insert secured in the outer housing, the insert including multiple longitudinally extending flow passages formed through the insert.