Abstract: A drill bit assembly for making a hole in a subterranean formation, the drill bit assembly comprising: a connector body defining a centreline axis about which said connector body rotates while drilling; a plurality of blade members connected to the connector body and circumferentially arranged around the centreline axis to form a cutting blade having an outer diameter generally equal to a desired hole diameter, wherein each blade member comprises at least one aperture for receiving a cutting pin; and a removable sleeve positionable within the at least one aperture, the removable sleeve configured to rotatably engage with the at least one cutting pin to allow the at least one cutting pin to rotate within the removable sleeve when the drill bit assembly operates to make the hole in the subterranean formation.

Abstract: A shroud system for a tubular string clamping device on a well platform is provided. The clamping device has a door pocket. The shroud system includes a cover frame and a cover door. The cover frame is configured to engage with the door pocket of the clamping device. The cover frame is also configured to define an access opening relative to the door pocket for access to an interior of the tubular string clamping device. The cover door is pivotally attached to the cover frame, and is pivotable between an open position and a closed position. The cover frame and the cover door are configured such that in the open position the access opening is uncovered thereby providing a passage through the door pocket and into the interior of the tubular string clamping device, and in the closed position access opening is covered by the cover door.

Abstract: A hydrojet rotary drill bit (10) is provided for drilling a hole in a subsurface formation. The bit body (12) includes a plurality of axially extending ribs (16a, b, c, d, e, and f) and a flow channel between adjacent ribs. A plurality of cutting elements are fixedly mounting on a respective one of the plurality of ribs. A plurality of flow nozzles (20a, b, c, d, e, and f) made on respective one of the plurality of ribs to direct fluid (mud) to a respective one of the plurality of cutting elements to clean and cool the cutting elements.

Abstract: A method for determining geological formation characteristics involves driving a bottom hole assembly (BHA) in a borehole. At least one mechanical drilling parameter generated is detected responsive to operation of the BHA in the borehole. At least one geological formation characteristic is identified responsive to the detected at least one mechanical drilling parameter. The identified at least one geological formation characteristic is provided to a surface steerable drilling system. Operation of the surface steerable drilling system is controlled responsive to the at least one geological formation characteristic.

Abstract: A spider can include a sensor that outputs measurements indicative of a distance between a location on the spider and a floor of a well rig, and a control system that controls actuation of slips of the spider between open and closed positions in response to the measurements. A method can include measuring a distance between a location on a spider and a floor of a well rig, and controlling actuation of slips of the spider between open and closed positions in response to the measuring. A system can include a spider with at least one slip that grips a tubular positioned in the spider, and a sensor that senses a rise of a location on the spider relative to a floor of a well rig.

Abstract: An earth-boring tool includes a tool body with two or more blades, multiple cutting elements secured to the blades, and at least one roller cone positioned between the blades. The tool includes cutting structures extending from the roller cone, with at least two rows of cutting structures. One of the rows is underexposed and inset from the cutting profile defined by the cutting elements on the blades.

Abstract: Provided is a cutting element, a drill bit, and a well system. The cutting element, in one aspect, includes a cutting section, the cutting element including a cutting section thickness (tc) and a cutting face. The cutting element, according to one aspect, further includes two or more shaped cutting features extending from the cutting face, wherein each of the two or more shaped cutting features is convex shaped, but also angles inwardly and downwardly from a radial exterior point of its shaped cutting feature to a radial interior point of its shaped cutting feature.

Abstract: A method and system to implement a technique including receiving at least one drilling parameter corresponding to an attribute related to a well in a formation as measured data, performing a first inversion operation (e.g., using machine learning methods) utilizing the measured data to generate first inversion result, determining whether the first inversion result meets a predetermined criteria related to quality of the first inversion result, and performing a geosteering operation based on the first inversion result when the first inversion result is determined to meet the predetermined criteria. If the first inversion result is determined not to meet the predetermined criteria, a second inversion operation (e.g., traditional methods) is used to invert the measured data to generate second inversion result, which is used for performing a geosteering operation.

Abstract: A method of forming an earth-boring tool includes providing a drill bit body with a nozzle cavity adapted to receive a nozzle and forming a first groove in the wall of the nozzle cavity at a first depth. A nozzle adapted to be inserted into the nozzle cavity is also provided. A second groove is formed in the nozzle at a second depth. The nozzle is inserted into the nozzle cavity such that the first groove and the second groove are aligned. A sealant is provided and cured on the interior of the nozzle cavity and/or the exterior of the nozzle.

Abstract: The present disclosure describes systems and methods for horizontal directional drilling. In some aspects, an elongated housing includes an interior, a front, a rear, and a longitudinal axis passing through the front and rear. A sonde transmitter is mounted in the interior. Additionally, a main fluid channel extends in the interior of the housing in a direction along the longitudinal axis to permit a flow of a fluid therethrough. A connecting region is used for attaching the drilling tool to the elongated housing, wherein the connecting region comprises a projection and a pocket, at least a portion of the projection being a mating rounded polygon, the pocket being shaped and sized to mate with the projection, and wherein the mating rounded polygon is configured to transmit torque between the transmitter housing and the drilling tool. The projection is located on one of the elongated housing and the drilling tool, and the pocket is located on the other of the elongated housing and the drilling tool.

Abstract: A system and method that provides an automated process for the trenchless construction marketspace. The system including a containerized unit consisting of a plurality of holding tanks, fluid agitators, hootenanny mixers, progressive cavity pumps and pneumatic valving. The operator of the system is capable of mixing costly polymer chemistries simultaneously while dosing the custom mixes into the active circulating system at a fixed rate.

Abstract: A system may include a fluid separator disposed within a lateral bore of a multilateral well. The fluid separator may be configured to receive formation fluid from a main bore of the multilateral well, separate the formation fluid into formation water and production fluid, and output the production fluid to flow uphole. The system may also include a lower lateral packer, disposed within the lateral bore in a position downhole from the fluid separator, and a downhole pump disposed in the lateral bore. The downhole pump is configured to receive the formation water from the fluid separator and pump the formation water to flow into a portion of the lateral bore downhole from the lower lateral packer.

Abstract: A method for drilling a second wellbore in proximity to a first wellbore includes obtaining a first trajectory for the first wellbore, drilling the second wellbore in proximity to the first wellbore, making wellbore surveying measurements in the second wellbore and computing the trajectory of the second wellbore, making ranging measurements at a plurality of ranging locations in a ranging interval of the second wellbore, and transforming the ranging interval of the second trajectory to fit selected ones of the plurality of ranging measurements.

Abstract: System and method for a permanent monitoring and control automation system for a well includes a grease tank including a storage container configured to hold grease, sensors for measuring grease volume in the grease tank and pressure levels, and a pump for greasing a valve at a pre-set pressure level value using grease from the grease tank. The system further includes a greasing control system for monitoring parameters, inputting parameters into an artificial intelligence model, determining pumping rate, volume, and time schedule, predicting a greasing maintenance schedule, and pumping grease. The greasing control system includes a computer processor connected to a remote terminal unit and a supervisory control and data acquisition. The system further includes an alert system for transmitting alarms to notify a user of system status. The alarms include low grease level on the valve, operational status, alert type, system malfunction, and grease tank low level.

Abstract: A slip for use in a hydraulic spider is provided. The slip including a slip body, a first insert coupled to the slip body, and a second insert coupled to the slip body. The first insert including a first engagement surface. The first engagement surface includes one or more first teeth oriented in a first direction. The second insert disposed below the first insert. The second insert including as second engagement surface. The second engagement surface includes one or more second teeth oriented in a second direction.

Abstract: A cutter element for a fixed cutter drill bit configured to drill a borehole in a subterranean formation includes a base portion having a central axis, a first end, a second end, and a radially outer surface extending axially from the first end to the second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion and a radially outer surface extending axially from the cutting face to the radially outer surface of the base portion. The cutting face includes a planar surface disposed in a plane oriented perpendicular to the central axis and a concave recess extending axially into the planar surface. The planar surface extends circumferentially about the concave recess. The planar surface has an average surface roughness Ra and the concave surface has an average surface roughness Ra.

Abstract: An electric submersible pump pod system includes an electric submersible pump (ESP), a pod casing, a connector housing, an electrical connector, and a cable. The ESP is fluidly coupled with a production string disposed within a wellbore. The pod casing is coupled with and houses at least a portion of the ESP such that an intake of the ESP is disposed within the pod casing. The pod casing is arranged to receive production fluid from the wellbore. The connector housing is coupled with the pod casing. The electrical connector is disposed at least partially within the connector housing and is electrically coupled with the ESP. The cable is electrically coupled with the electrical connector and is fluidly isolated from the production fluid within the pod casing.

Abstract: A method for designing, monitoring, and updating a trajectory of a wellbore at a wellsite. The method includes receiving a plurality of inputs related to the trajectory for the wellbore. The inputs may include a starting point of the trajectory. A zone may be defined within a subsurface beneath the wellsite as safe. The method further includes defining a first set of control points within the zone of the subsurface, and generating a proposed path of the trajectory by connecting the starting point of the trajectory to a plurality of trajectory targets via the first set of control points. The method also includes validating that the proposed path of the trajectory is within the zone of the subsurface.

Abstract: Aspects of the subject technology relate to tools, system and methods related to a drilling tool that is fabricated using a bimetallic member that is subjected to an infiltration process. The method can include having an amount of precipitation hardenable steel and an amount of another type of steel. The precipitation hardenable steel and the other type of steel are metallurgically bonded to form a bimetallic member including a casting mandrel portion and a drill string connection portion. A reinforcing powder is infiltrated with a binder while in contact with the casting mandrel portion to form a metal matrix composite about the casting mandrel portion. A cutting structure is fabricated into the metal matrix composite of the drilling tool.

Abstract: A method for estimating and reducing high-frequency torsional oscillations (HFTO) during a downhole drilling operation includes estimating an HFTO propensity of an initial BHA configuration using a model that relates the HFTO propensity to at least a rock strength of a subterranean formation, a radius or diameter of the borehole, a drill bit body density, and a drill bit body radius or diameter. The estimated HFTO propensity is compared with an HFTO propensity threshold. The model is used to select a modified drill bit or bottom hole assembly (BHA) configuration that reduces the estimated HFTO propensity to a value below the HFTO propensity threshold. The modified drill bit or BHA configuration has an increased polar moment of inertia as compared to the initial drill bit or BHA configuration.