Abstract: An apparatus, system, and method according to which one or more sensors are adapted to detect a presence or absence of fluid entering, or before entering, a lubricator, within the lubricator, exiting, or after exiting, the lubricator, or any combination thereof, while fluid flow is received into the lubricator, the lubricator being operably coupled to a wellhead used in oil and gas operations. Based on the one or more sensors detecting the presence or absence of fluid, additional fluid flow into the lubricator is impeded.

Abstract: A method including deploying a formation testing tool in a borehole, actuating first and second packers of the formation testing tool in the borehole, obtaining measurements in response to actuation of the first and second packers of the formation testing tool in the borehole, and analyzing the measurements to estimate at least a shear modulus (G) of a geological formation surrounding the borehole.

Abstract: Embodiments of a high flow, tubing insensitive, deep set wireline retrievable safety valve are disclosed herein. In one embodiment, a valve system for use downhole in a wellbore comprises a tubing retrievable safety valve (TRSV) and a secondary safety valve to be positioned within the TRSV. The secondary safety valve comprises at least a valve body having a valve seat at a downhole end; a piston; a rod coupled with the piston; a control line; a first pressure communication port, communicatively coupling the control line of safety valve with the TRSV control line; a balance line; and a second pressure communication port, communicatively coupling the balance line of the safety valve with the TRSV balance line; wherein the control line is configured to actuate the safety valve between an open position and a closed position in response to an intentional pressure change in the control line.

Abstract: Provided is a coiled tubing deployment/retrieval apparatus, a coiled tubing surface equipment spread, and a method. The coiled tubing deployment/retrieval apparatus, in one aspect, includes a frame, a coiled tubing guide coupled to the frame, and a coiled tubing injector coupled to the frame, the coiled tubing injector configured to insert or retrieve a coiled tubing string guided by the coiled tubing guide into or out of a wellbore. The coiled tubing deployment/retrieval apparatus, in one aspect, further includes a power cable injector coupled to the frame, the power cable injector configured to insert or retrieve a power cable into or out of the wellbore alongside the coiled tubing string.

Abstract: Systems and methods for landing a tubing hanger in a wellhead and then orienting a tree (or spool, or flowline connection body) relative to the tubing hanger while landing the tree on the wellhead are provided. This alignment is accomplished without the use of either a tubing spool or a BOP stack with an orientation pin. The tubing hanger alignment devices may be used to orientate the tree as the tree is landed so that the couplings and stabs between the tree and the tubing hanger line up with each other just at the moment of landing.

Abstract: Embodiments of the invention relate to methods, systems, and software for identifying and quantifying subsurface hydrogen, helium, carbon dioxide, or other fluids using multiple indicia from geophysical well logs, other wireline logging tools, or mudlogging tools.

Abstract: A brake system for maintaining an angular position of a spindle assembly. A pump-powered motor drives rotation of a spindle on the machine. When no rotation is desired, the spindle will slow, then stop at a desired angular orientation. A rotational sensor will determine the clock position, and a controller compares that to a desired angular orientation. If an error tolerance is exceeded, the motor will rotate the spindle back to the desired orientation.

Abstract: Provided is a two part drilling and running tool, a downhole tool, a well system, and a method for forming a well system. The two part drilling and running tool, in at least one aspect, includes a smaller assembly coupled to an end of a conveyance, the smaller assembly having a spline or slot located along an entire length (LS) thereof. The two part drilling and running tool, in accordance with this aspect, further includes a larger bit assembly slidably coupled to the conveyance, the larger bit assembly including an other of the slot or spline, wherein the spline or slot in the smaller assembly and the other of the slot or spline in the larger bit assembly are configured to engage one another to rotationally fix the smaller assembly relative to the larger bit assembly as the smaller assembly and the larger bit assembly slidingly engage one another.

Abstract: A chemical injection system includes an electric submersible pump (ESP) and a fluid chamber. The ESP lifts a production fluid through a production string disposed within a wellbore. The fluid chamber is coupled with the ESP and houses a treatment fluid. The fluid chamber defines, together with a wall of the wellbore, an annulus. The ESP flows at least a portion of the production fluid into the fluid chamber to push the treatment fluid out of the fluid chamber into the annulus, allowing the treatment fluid to flow from the annulus into the ESP to treat the ESP.

Abstract: A system includes a container unit and a processor. The container unit includes a first fluid pathway having an inlet configured to couple to a first component of a drilling fluid circulation system, and having an outlet configured to couple to a second component of the drilling fluid circulation system. The container unit also includes a second fluid pathway having an inlet configured to couple to a third component of the drilling fluid circulation system, and having an outlet configured to couple to the third component. The container unit includes a first sensor coupled to the first fluid pathway and a second sensor coupled to the second fluid pathway. The processor is configured to determine a drilling fluid profile based on data from the sensors, and compare the determined drilling fluid profile to a target drilling fluid profile to determine an adjustment for an actual drilling fluid profile.

Abstract: A wellhead pusher tool and method for replacing a tubing hanger. The tool includes an upper body coupled to the tubing hanger including an internal section, a lower body fitted inside the internal section, a piston assembly, and a control line hydraulically connected to the chamber. The lower body moves inside the upper body via a sliding face in the internal section. The piston assembly includes a piston which moves inside a chamber and a spring mechanism. The control line injects and removes fluid from the chamber to move the piston to compress and expand the spring mechanism. The lower body slides towards the tubing as the piston compresses the spring mechanism thereby pushing the tubing hanger out of a tubing spool as the upper body is pushed towards the tubing hanger. The tubing hanger is removed once the tubing hanger is pushed out of the tubing spool.

Abstract: Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.

Abstract: Systems and methods for landing a tubing hanger in a wellhead and then orienting a tree (or spool, or flowline connection body) relative to the tubing hanger while landing the tree on the wellhead are provided. This alignment is accomplished without the use of either a tubing spool or a BOP stack with an orientation pin. The tubing hanger alignment devices may be used to orientate the tree as the tree is landed so that the couplings and stabs between the tree and the tubing hanger line up with each other just at the moment of landing.

Abstract: A drilling control system may receive a target toolface and rate of penetration (ROP) and receive a first toolface and ROP. The system may calculate a toolface error based at least in part on a difference between the target and first toolface and calculate a ROP error based at least in part on a difference between the target and first ROP. The system may determine an additional reactive torque for correcting ROP error, generate one or more spindle changes based at least in part on toolface error and additional reactive torque, and generate one or more block speed changes based at least in part on ROP error. The system may send one or more control signals to one or more control systems coupled to the drilling rig to implement and drill in accordance with the one or more spindle changes and the one or more block speed changes.

Abstract: A variety of methods and apparatus are disclosed, including, in one embodiment, a downhole tool for use in a borehole, comprising: a mandrel; and a sealing element disposed about the mandrel, wherein the sealing element comprises an aromatic copolyester thermoset (ACT).

Abstract: A bottom hole assembly includes a housing, a drill bit, a first flow path, a pump, a power source, and a second flow path. The housing defines a flow channel therethrough for receiving a fluid from a drill string. The first flow path being defined through the drill bit between a first inlet port and a first nozzle, the first inlet port fluidly coupled to the flow channel. The pump being disposed in the housing and having a pump inlet fluidly coupled to the flow channel, the pump being configured to pressurize a fluid and discharge the fluid through a pump outlet. The power source being coupled to the housing and operable to drive the pump. The second flow path being defined through the drill bit and extending between a second inlet port and a second nozzle, the second inlet port fluidly coupled to the pump outlet.

Abstract: A drilling system may include a steering tool configured to engage a wellbore wall to direct an orientation of a toolface, the steering tool being rotatable about a rotational axis. A drilling system may include an azimuth sensor package, the azimuth sensor package including at least one of a multi-axis gyroscopic azimuth sensor rotatable about the rotational axis of the steering tool, a multi-axis magnetic azimuth sensor rotatable about the rotational axis of the steering tool, or an accelerometer azimuth sensor rotatable about the rotational axis of the steering tool.

Abstract: A technique facilitates reliable operation of a blowout preventer (BOP) system. The reliable operation is achieved by utilizing a ram with improved strength so as to make it better able to resist the stresses from shearing without increasing the thickness of the ram blade. As a result, a high level of efficiency is maintained during a shearing action. According to an embodiment, a blowout preventer system comprises a blowout preventer shear ram assembly having a ram for shearing a tubular member. The ram comprises a main body and a blade extending from the main body. Additionally, a ramp buttress is secured to the blade to strengthen the blade and to improve the shearing action.

Abstract: The invention relates to a drilling assembly for earth or rock drilling, comprising an inner rod, which comprises, at its distal end facing the ground, an inner drilling tool for removing ground material, and which can be connected, at its proximal end, to a rotary drive for the transmitting a drilling torque, a tubular outer rod, which surrounds the inner rod and comprises, at its distal end, an annular drill bit for removing ground material, and an impact unit, which is arranged on the inner rod in the region of the distal end and is configured to exert axially directed impacts on the inner drilling tool, wherein, in the region of the distal end, a radial connecting apparatus is arranged and configured between the inner rod and the outer rod, which connecting apparatus allows torque to be transmitted from the rotationally driven inner rod to the drill bit of the outer rod.

Abstract: A pullback device for connection with a rotary drill bit of a horizontal directional drill string. The pullback device includes an anchoring portion and a plurality of arms with ends configured to engage a plurality of corresponding engagement features of the rotary drill bit.