Abstract: Techniques for removing a tubular from a wellbore include running a downhole tool on a downhole conveyance into a wellbore formed from a terranean surface into a subterranean formation; activating a piston sub-assembly to repeatedly move pistons to contact a portion of a casing installed in the wellbore to at least de-bond a cement layer installed between the portion of the casing and the subterranean formation from the portion of the casing; activating a cutting sub-assembly to move a cutting blade to cut through the portion of the casing adjacent the de-bonded portion of the cement layer; activating a hanger sub-assembly to move a set of slips into contacting engagement with the cut portion of the casing; and running the downhole tool on the downhole conveyance out of the wellbore with the cut portion of the casing engaged with the set of slips.

Abstract: A drilling mud screen comprising: a body having a first end and a second end and a centerline, wherein the first end and/or the second end of the body has a means to engage a drilling mud screen puller/installer tool; a drilling mud inlet at the first end of the body; a filter having a first end, a second end, and openings, wherein the filter is fluidly connected to the second end of the body via a first connection and/or an optional first end retaining ring; a drilling mud outlet at the openings of the filter; and a second end cap fluidly connected at the second end of the filter via a second connection, wherein the filter has an optional retaining ring disposed between the first connection and the second connection is disclosed.

Abstract: A tool is provided for expanding the casing at one or more locations for arresting surface casing vent flow in an abandoned well. A setting tool is run into the bore having an expansion element supported thereon. The setting tool imparts a large axial force to radially expand the expansion element for plastically deforming the casing. A single use, pleated ring crushable expansion element can be actuated and left downhole. The pleated ring tool can be pre-charged with a highly viscous fluid, semi solid for transport, but plastic under load. A multi-use expansion element can be actuated, released, moved and actuated again at successive locations.

Abstract: An exemplary automated system and method are provided for monitoring and controlling the transfer of water to water tanks or containers during a water transfer process. In one embodiment, the automated system includes a first manifold, a plurality of controllable valves, a plurality of level indicators, a pump, controller(s), storage device, and display. In one implementation, the controller is configured to control the opening/closing of the plurality of controllable valves based, at least in part, on the water levels of the frac water tanks. The controller(s) may include one or more control modes. In other implementations, the system may include a second manifold (or additional manifolds) and the capability to blend water from two or more sources, such as from an impaired water source, using either a single or multiple-manifold configuration. In other implementations, an assembly is provided, such as a skid or trailer mounted assembly, for use in a mobile automated system.

Abstract: A horizontal directional drilling machine having a modular pipe loader system. The system comprises a first and second pipe loader assembly supported on a drill frame. Each assembly supports a shuttle arm. The shuttle arms are configured to move independently of one another along a shuttle path that is traverse to a longitudinal axis of the drill frame. Movement of each shuttle arm is powered by an actuator supported on each pipe loader assembly. Each pipe loader assembly includes a sensor used to measure parameters related to the position of each shuttle arm relative to the drill frame. A controller analyzes the measured parameters and directs operation of each actuator in order to keep the shuttle arms moving in unison during operation.

Abstract: The disclosed embodiments include gravel pack assemblies, method to bypass a fluid restrictor during gravel packing operations, and methods to control fluid flow during and after gravel packing operations. In one embodiment, a gravel pack assembly including a flow restrictor that is coupled to a downhole string that is deployed in a borehole is disclosed. The flow restrictor forms a first fluid passageway from the borehole to an internal cavity of the string. The gravel pack assembly includes a fluid bypass portion having a first chamber, a sealing member inserted into the first chamber; and an actuation assembly operable to actuate the sealing member. The fluid bypass portion forms a second fluid passageway from the borehole to the internal cavity of the downhole string prior to actuation of the actuation assembly. After actuation of the actuation assembly, fluid flow through the second fluid passageway is restricted by the sealing member.

Abstract: A floating drift apparatus for verifying the inner diameter of tubulars as the tubulars are made up into a tubular string being run into a wellbore. A float section provides buoyancy to float the apparatus in fluid within the bore of a tubular, and a drift section has a drift element with a diameter substantially equal to the tubular inner diameter being verified, which may be the drift diameter. When running a tubular string, the apparatus is inserted into the bore of the tubular string, floating in the fluid. As joints of tubular are made up and run into the wellbore, the tubulars move downhole around the apparatus. Preferably, the floating drift apparatus can be visually detected. If an undersize ID is encountered, the floating drift apparatus will be pushed downhole and no longer visible; the operator can remove the undersize ID tubular from the string.

Abstract: An apparatus, method, and system for inserting and securing a high pressure transition tube of a fluid transfer tool assembly into a positive position whereby the seal element is packed off in the wellhead set point. Once attached the transition tube is pushed to contact the bit guide, secondary seal or bore machine prep. A lower nose compression seal is seated against transition tube and compressed using an energizer seal to isolate and protect lower pressure wellhead and well control equipment from the higher rated frack pressures or pushing the transition tube and lower nose isolation compression seal to contact the bit guide, secondary seal or bore prep. Pressure is applied to push a seal against the lower and upper compression ring locking them in place preventing movement to form a compression seal and isolating the high pressure passing through the transition tube protecting the wellhead assembly and well control equipment.

Abstract: Provided herein, is magnetic catch assembly that may be utilized with and/or incorporated into lubricator of a wellhead. The magnetic catch assembly permits maintaining a plunger within the lubricator without requiring any moving mechanical components.

Abstract: A method of assembling an optical fiber cable on production casing includes positioning the optical fiber cable against a production casing at a hole of a well site, and affixing the optical fiber cable against the production casing by applying an adhesive to the production casing to secure the optical fiber cable against the production casing. The method further includes applying pressure to the adhesive to adhesively bond the optical fiber cable to the production casing along a length of the production casing while the production casing is being run-in-hole.

Abstract: A system and method for hydraulic isolation of a downhole powered system. The system and method include a sliding sleeve, venting assemblies with venting ports, and check valves associated with a vent body, and an isolation sleeve, isolation valve, and integral packer for controlling fluid flow through the motor and pump assembly of the powered system. Also disclosed is a wet connect mandrel modified to receive the isolation sleeve, the isolation sleeve preferably capable of permitting the passage of tools therethrough and capable of preventing fluid through the inlet of the mandrel. The mandrel may also be outfitted with a built in sliding sleeve. The sleeves, valves and packer can be actuated mechanically, hydraulically or electrically. Electrical actuation can be facilitated using the power from an adjacent wet connect mandrel.

Abstract: Gas and liquid velocities of fluid in a lift gas assisted well system are estimated by adding liquid and gas tracers downhole and monitoring their travel time over a known distance. Based on estimated velocities, a slip factor is obtained that represents relative velocities of the gas and liquid in the fluid. A flow regime of the fluid is identified based on the slip factor. The flow regime is optionally altered by adjusting one or more operational parameters of the well.

Abstract: A junction for use in a multilateral completion system is presented. The junction comprises a metal sealant applicable to a lateral component of the multilateral completion system. The metal sealant is expanding in response to hydrolysis and after activation forms a seal and an anchor with a well casing or tubing of the multilateral completion system. The metal sealant is expanding in response to one of an alkaline earth metal hydrolysis and a transition metal hydrolysis. More specifically, the metal sealant is expanding in response to one of magnesium hydrolysis, aluminum hydrolysis, calcium hydrolysis, and calcium oxide hydrolysis.

Abstract: Control valves can allow a well operator to steer a drill string. An exemplary control valve can include a valve body with an axial bore and a radial orifice in fluid communication with the axial bore, wherein flow passing through the axial bore passes through the radial orifice and into a piston flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled a steering pad for applying force against the wellbore wall. A rotary valve element is disposed within the axial bore and including an actuation flow channel, wherein the rotary valve element is rotatable with respect to the axial bore to change flow through the actuation channel and the radial orifice to modify fluid pressure within the piston flow channel that is exerted against the piston.

Abstract: A system and a method are for positioning a drilling rig arranged to drill in a ground. The system has a positioning jig including at least one coupling portion; a drilling rig including at least two coupling portions; and at least two anchoring elements including an upper coupling portion and a lower coupling portion. The lower coupling portion of the anchoring element is arranged to be releasably fixed to the ground. The upper coupling portion of the anchoring element is arranged to be connected to the coupling portion of the positioning jig and to the coupling portion of the drilling rig, so that the upper coupling portion of the anchoring element can optionally be connected to the positioning jig or the drilling rig.

Abstract: A hybrid drill bit includes both fixed cutting elements and an adjustable cutting structure thereon. An adjustment mechanism is provided to allow an axial position of cutting elements at a leading end of the adjustable cutting structure to be adjusted with respect to an axial position of the fixed cutting elements. The adjustable cutting structure may include counter rotational cutting members mounted obliquely with respect to a bit body rotational axis, and the adjustment mechanism may dynamically support the adjustable cutting structure such that the axial position of the cutting elements may be adjusted as the drill bit is in operation within a wellbore. The axial position may be adjusted by altering a weight applied to the drill bit within the wellbore.

Abstract: A method performed during a run-in-hole process for a casing section includes applying pressure to a cable against an outer portion of the casing section. Additionally, the method includes ultrasonic welding the cable to the outer portion of the casing section while the pressure is applied to the cable against the outer portion of the casing section.

Abstract: A system and method for stall recovery of mud motors may be implemented in a steering control system. The stall recovery system and method may involve automatic detection of a stall of a mud motor during drilling controlled by the steering control system, and may respond to the stall in a rapid and controlled manner to avoid or minimize damage to the mud motor, such as by immediately reducing mud pressure and stopping rotary drilling, if used, faster than a typical human operator could perform. The stall recovery system and method may farther take actions to automatically restart drilling.

Abstract: Tagging bottom utilizing an automated control system and downhole tools may include determining, by a computer processor, that a drill bit has reached a predetermined distance from a bottom of a wellbore, in response to determining that the bit has reached the predetermined depth, transmitting a rate of penetration set point to reduce a lowering speed of the drill bit, directing the drill bit based on the rate of penetration, determining, by the computer processor, that the rate of penetration is stable, in response to the determining that the rate of penetration has stabilized, automatically taring a surface weight on the drill bit and a differential pressure, and in response to determining that the bit is within a predetermined off bottom range, monitoring for a true bottom based on one or more parameter triggers.

Abstract: Systems and methods include a computer-implemented method for performing an advanced control policy for a group of wells. Choke settings are applied to one or more control elements of each well in a group of wells. Rig control settings are applied to the group of wells. The rig control settings define, for each rule in a set of rules: a rule count limiting a number of times a rule is to be executed in a simulation run and a rule frequency identifying a time frequency by which the rule is to be executed during the simulation run. Settings are received for targets and constraints for the group of wells. The simulation run is executed for the group of wells using the choking settings, the rig control settings, and the settings for of the targets and constraints for the group of wells.