An environmentally beneficial process for utilizing waste drill cuttings from oil and gas exploration. The waste drill cuttings (20) are used as a filler and combined with plastic to provide a plastic based product (26) in the plastics industry. In an embodiment the cuttings are thermally treated and formed into pellets. In a further embodiment the cuttings are treated and mixed with recycled plastic to be formed into pellets. The pellets are then used in the manufacture of rigid plastic products such as bollards, planters, benches and decking.

A section member drilling or milling machine comprises a machine bed for supporting a workpiece to be drilled, the machine bed including guides for controllably sliding thereon a support comprising precision vertical guides thereon a platform is engaged, the platform comprising parallel horizontal guides slidably supporting a carriage, in turn supporting a cantilever arm, including a driving motor for controllably driving a drilling and milling tool along parallel guides of the cantilever arm.

A method for preparing lignin graft copolymer comprising: reacting lignocellulosic materials with an acrylic compound by bulk condensation under nitrogen atmosphere in the presence of a non-oxidizing strong organic acid as catalyst; separating the reaction mixture to obtain a solid phase mainly containing lignocellulosic materials and a liquid phase containing lignin graft copolymer and unreacted acrylic compound; and removing solvent from the liquid phase to obtain the lignin graft copolymer.

A video-on-demand (VOD) content delivery system has a VOD Application Server which manages a database of templates ordered in a hierarchy for presentation of video content elements of different selected types categorized in hierarchical order. The templates include those for higher-order displays which have one or more links to lower-order displays of specific content. The VOD Application Server, in response to viewer request, displays a high-order templatized display, and in response to viewer selection of a link, displays the lower-order display of specific content. The hierarchical templatized displays enable viewers to navigate to an end subject of interest while having a unique visual experience of moving through a series of displays to the end subject of interest.

A dust suction device for detachable attachment to a hand-held drilling machine includes a housing, a telescoping suction pipe coupled to the housing, an electric motor positioned in the housing, a suction fan driven by the electric motor and operable to generate a vacuum in the suction pipe, a dust collection container coupled to the housing and positioned upstream of the suction fan, and a support frame. The support frame includes a first portion coupled to the housing, a second portion coupled to a neck of the drilling machine, and an auxiliary handle extending from one of the first and second portions of the support frame. The support frame supports the drilling machine in a side-by-side relationship with the dust suction device.

A core drilling machine having an axial extending hollow drill shaft supported rotatably in a housing and rotated by means of a drive unit; a coaxial tool holder receiving an axially displaceable drill bit, the tool holder having a locking mechanism securing the drill bit in a rotationally fixed manner to the hollow drill shaft; wherein the hollow drill shaft is suitable for receiving a shaft of an interchangeable centre drill, the center drill axially supported against a first spring element; and an axial stop element preventing in a first position a complete displacement of the center drill into the interior of the hollow drill shaft and allows in a second position a complete displacement of the center drill into the interior of the hollow drill shaft; and an activation device for activating the first or second positions of the stop element.

A drill insert of the present invention comprises a corner part, and an upper face having a first side and a second side disposed on both sides of the corner part, respectively. The drill insert comprises a first cutting edge formed along the first side; a second cutting edge formed along the second side; a first region of the upper face located along the first cutting edge; a second region of the upper face located along the second cutting edge; and a first raised part disposed in the first region so as to lie at a higher position than the second region. The first raised part has an upper portion; a breaker portion configured to be inclined so as to become at a lower position as the first raised part extends from the upper portion; and a side portion configured to be inclined so as to become at a lower position as the side portion extends from the upper portion. The first raised part is disposed at a position closer to the first cutting edge than a bisector of the corner part when viewed from above.

The invention relates to a modular drill including a shank part with an end side. A cutting part can be connected to the shank part at its end side. The shank part has at least one torque transmission element which projects on the end side and has at least one torque transmission face for transmitting a torque in the rotational direction from the shank part to the cutting part. The cutting part has at least one torque receiving region for receiving the torque. The at least one torque receiving region has at least one torque receiving face which corresponds with the torque transmission face. The cutting part has at least one centering element for radially centering the cutting part in relation to the shank part. The cutting part is clamped to the shank part via a clamping element which acts at least predominantly in the axial direction.

The invention relates to a multiple edge drill such as is especially used for machining difficult-to-machine, e.g. high-toughness materials, such as e.g. cast steel, steel for hardening and tempering or other difficult-to-machine steel materials including metallic cast materials, such as e.g. gray cast iron, and especially GGV or ADI cast iron. The facet is designed in such a manner that the main cutting edge has at least two main cutting edge sections that define point angles of different size, the radially outer point angle being smaller than the radially inner one, thereby obtaining a good cutting behavior and long service life of the tool.

A solid step drill, including a front tip and a rear end between which a center axis extends and around which the drill is rotatable in a predetermined direction. At least two cylindrical sections are concentric with the center axis, a first section extending rearward from the front tip and having a first diameter, and a second section extending behind the first section and having a second diameter that is greater than the first diameter, the first section transforming into the second section via a step. The tip includes two primary cutting edges, which individually co-operate with a respective chip flute that is delimited by a concave surface and countersunk in the first section and in the second section, the respective chip flute intersecting the step while forming a secondary cutting edge. Adjacent to the secondary cutting edge, a chip breaking recess is formed between a cutting edge line of the cutting edge and the concave surface.

An adjustable drill is provided comprising a drill body having at least one face surface with a plurality of serrations provided therewith. The drill further has at least one cartridge having a cooperating plurality of second serrations, to be driven with the drill body when assembled therewith. The at least one cartridge includes at least one insert pocket, and at least one insert is releasably affixed in the insert pocket provided in the cartridge. In further examples, the adjustable drill may have a central cutting system in combination with the adjustable cartridge type system, wherein the central cutting system may be modular. There may also be provided a modular type of holder arrangement to provide flexibility to adapt the system for various applications.

Chips are segmented to have a desired width and the chip controllability is improved and the tool rigidity is improved. A drilling tool is provided that includes: a tool body; a chip discharge groove formed at the outer periphery of the tool body; at least one sub-groove formed at an inner face facing the front side in the tool rotation direction T of the chip discharge groove; a rake face; a tip end flank face; and a cutting edge formed at a ridge line at which the tip end flank face intersects with the rake face. The plurality of rake faces form a step-like shape having at least one step section. The drilling tool is configured so that the turnup section of the sub-groove is turned up in a different direction from the direction along which the turnup section of the chip discharge groove is turned up.

The invention relates to a multi-blade solid carbide drill for cutting high-strength sandwich materials. The tool comprises a shaft section and an adjoining cutting part, into which a number of chip flutes that corresponds to the number of main blades is incorporated. In order to reinforce the curvature of the resulting chip, the chip flute of the drill comprises a chip flute rib in the region of the chip formation zone, said rib protruding from the chip flute surface and having a substantially wave-shaped cross-section (28), and said rib dividing the chip flute into two sections, a first chip flute section (30) forming the cutting rake and a second chip flute (32) forming the chip flute runout.

A drill bit assembly has a bit head and a pin body. The bit head comprises a cutting end, an opposite connecting end with an engagement section, and a feature facing the connecting end. The pin body comprises a tubular body with an axial bore therethrough, a connecting end with an engagement section and a feature facing the connecting end. The drill bit assembly is manufactured by positioning the pin body connecting end with the bit head connecting end such that the pin body and bit head engagement sections overlap with a gap therebetween, and the pin body and bit head features are aligned; injecting a thermoplastic or other connecting material in liquid form between the bit head and pin body engagement sections and into the gap; and solidifying the thermoplastic or other connecting material such that the bit head and pin body are mechanically coupled together at their connecting ends and their features are securely aligned.

A foldable feed rail for a rock drill is composed of two segments, a first beam defining a first rail segment and a second beam defining a second rail segment. The second beam may be pivotally connected to the first beam with a hinge to enable the second beam to be folded relative to the first beam. Alternatively, the second beam can be detachably connected to the first beam so that the second beam can be removed altogether from the first beam. This invention enables the feed rail to be shortened, thereby making the feed rail much easier to maneuver in mines.

The invention concerns a drill bit, intended to be used with a down-the-hole drill and comprising a drill head (2) with a front surface provided with drill pins (3) and a shaft (4), whereby the shaft is narrower than the drill head and intended to be inserted in a manner that allows axial sliding into the end of a drill chuck that is a component of a down-the-hole drill and which shaft has a rear end part (6) that is somewhat thickened with a plane striking surface (7) against which a hammer piston (8) that is a component of the down-the-hole hammer drill is arranged to impact, that the drill head when viewed along its axial direction has a cylinder-shaped forward part (20) provided with cuttings channels (22), a rear cylinder-shaped part (21) that is located for the reception of drill cuttings at the same level or somewhat below the bottom (25) of the cuttings channels, whereby the diameter (D1) of the forward part is greater than the diameter (D2) of the rear part. In a drill bit that has high performance and a long useful life, and that is furthermore well-suited to be used for directed drilling, the cylinder-shaped forward part (20) of the drill head (2) has an axial length (L3) from the main plane of the front surface to a shoulder plane (26) located between the drill head (2) and the shaft (4) that is greater than the axial length (L4) of the cylinder-shaped rear part (21) of the drill head.

A tubular string is advanced with a bottom hole assembly as the hole is drilled and reamed in a desired direction with the aid of directional drilling equipment adjacent the bit. When the advanced tubular forms the desired lap to the existing tubular, the assembly can be configured to cement the tubular and expansion can then be accomplished to fill the annular space and enhance the cement bonding. The expansion equipment can create a bottom bell on the expanded tubular and expand the top end into a bell of the existing tubular so that a monobore is created as the process is repeated with each added string. Numerous variations are contemplated for each single trip including but not limited to the direction of expansion, whether cementing or expansion occurs first, reforming folded tubing in the hole as well as the nature of the expansion tool and pressure control when drilling.

A drilling apparatus for drilling boreholes in an underground formation includes a tool body that can be positioned in a borehole where drilling is to take place. The apparatus further includes a gas cutting torch having a nozzle, a supply of a cutting gas connected to the gas cutting torch. In some embodiments, the gas cutting torch and supply of cutting gas may be connected by an umbilical link. The tool body may be advanced through the borehole as drilling takes place. In some embodiments, the tool body may be advanced via a tractor device that forms part of the tool body or attached to the tool body.

Methods and systems are described for improved drilling operations through the use of real-time drilling data to predict bit wear, lithology, pore pressure, a rotating friction coefficient, permeability, and cost in real-time and to adjust drilling parameters in real-time based on the predictions. The real-time lithology prediction is made by processing the real-time drilling data through a multilayer neural network. The real-time bit wear prediction is made by using the real-time drilling data to predict a bit efficiency factor and to detect changes in the bit efficiency factor over time. These predictions may be used to adjust drilling parameters in the drilling operation in real-time, subject to override by the operator. The methods and systems may also include determining various downhole hydraulics parameters and a rotary friction factor. Historical data may be used in combination with real-time data to provide expert system assistance and to identify safety concerns.

An attitude hold controller method includes receiving at a navigable apparatus a demand inclination and a demand azimuth with respect to a global coordinate system and determining at the navigable apparatus a demand attitude vector according to the received demand inclination and the demand azimuth. Determining at the navigable apparatus a current navigable apparatus attitude vector. Evaluating a control law using the current navigable apparatus vector and the navigable apparatus demand attitude to derive a control law tool face, converting the control law tool face to an equivalent tool face, and applying the equivalent tool face with the navigable apparatus to control the navigable apparatus attitude.

The invention relates to a method and apparatus for opening threaded joints of drilling equipment (6) by striking the drilling equipment (6) with the percussion device of a rock drilling rig (1) and by measuring vibration originating from the drilling equipment (6) during striking. In addition to vibration, measuring means (9) measure a parameter defining at least one additional condition, on the basis of which the decision to stop striking is made.

Described herein is a wear indicator (100) for use in a drill bit or a core head. The wear indicator (100) comprises an elongate element that forms part of the drill bit. The elongate element has a plurality of numbers (110, 120, 130, 140, 150, 160, 170, 180) formed along its length, each number (110, 120, 130, 140, 150, 160, 170, 180) being formed as a void and corresponds to a level of wear in accordance with the IADC dull grading system. As the drill becomes worn, the wear indicator (100) wears at the same rate to reveal one of the numbers (110, 120, 130, 140, 150, 160, 170, 180). The numbers range from “1” to “8” where the number “1” illustrates the least wear and the number “8” indicates the most wear. When unworn, none of the numbers are visible.

A drill bit assembly for measuring reservoir formation properties comprises a bit head and a pin body, and an electrically insulated gap joint between two conductive parts of the drill bit assembly. The bit head has a cutting end and an opposite connecting end with an engagement section. The pin body comprises a connecting end with an engagement section. The pin connecting end is connected to the bit head connecting end such that the engagement sections overlap. The electrically insulating gap joint can fill a gap between the bit head and pin body engagement sections such that the bit head and pin body are mechanically connected together at the connecting ends but electrically separated. Alternatively or additionally, the pin body can have two pieces which are separated by an electrically insulating gap joint. An electrical conductor is electrically connected at a first end to the bit head and is communicable at a second end with an alternating current signal to transmit an alternating current into the bit head, thereby inducing an electric current into a reservoir formation adjacent the bit head. Electronic equipment includes measurement circuitry configured to determine the alternating current at the bit head, the alternating current being inversely proportional to a bit resistivity of the formation.

In some example embodiments, a system includes a drill string having a drill bit. The drill string extends through at least part of a well bore. The system also includes a first vibrational sensor, positioned on the drill bit to measure, at a first location on the drill string, an amplitude of one or more of an axial vibration and a lateral vibration. The system also includes a second vibrational sensor, positioned above the drill bit and on the drill string. The second vibration sensor is to measure, at a second location on the drill string, one or more of an axial vibration and a lateral vibration. The system includes a processor unit to determine a type of vibration based on a comparison of the amplitude at the first location to the amplitude at the second location, wherein the type of vibration is at least one of bit whirl of the drill bit and a while of a bottom hole assembly that is part of the drill string.

According to an embodiment, a drilling fluid comprises: water and a set accelerator, wherein the drilling fluid has a 10 minute gel strength of less than 20 lb*ft/100 sq ft, wherein the drilling fluid has a density in the range of about 9 to about 14 pounds per gallon, wherein the drilling fluid remains pourable for at least 5 days, and wherein when at least one part of the drilling fluid mixes with three parts of a cement composition consisting of water and cement, the drilling fluid cement composition mixture develops a compressive strength of at least 1,200 psi. According to another embodiment, a method of using the drilling fluid comprises the steps of: introducing the drilling fluid into at least a portion of a subterranean formation, wherein at least a portion of the drilling fluid is capable of mixing with a cement composition.

Systems and methods for processing drilling data. One embodiment provides a method comprising building user-designed contexts (which can be designated as built-in contexts) for drilling structures. The method also comprises orchestrating module execution within the user-designed contexts. The method further comprises providing data from the user-designed contexts to such modules via an interface. Some methods include monitoring drilling data to detect events (for instance departure from a pseudolog) and orchestrating module execution responsive thereto. The method can include exposing the orchestration of the execution of the module instances as a service. Moreover, some embodiments provide extra-contextual application program interfaces. In addition, or in the alternative, some embodiments schedule the orchestration of the modules based on declarations related to the inputs and/or outputs of the modules.

Mobile drilling devices and systems, methods, and computer-readable media for controlling such devices are provided. One method includes receiving user input from a user of a mobile computing device. The method further includes transmitting data based on the user input from the mobile computing device to a control circuit of a mobile drilling device via a wireless network connection. The method further includes generating a plurality of control signals based on the data received from the mobile computing device. Each of the plurality of control signals is configured to control movement of a separate one of a plurality of movement devices of the mobile drilling device. The plurality of movement devices are configured to move the mobile drilling device between locations.

A control and monitoring system controls and monitors a high power laser system for performing high power laser operations. The control and monitoring system is configured to perform high power laser operation on, and in, remote and difficult to access locations.

In at least some embodiments, a pulsed-electric drilling system includes a bit that extends a borehole by detaching formation material with pulses of electric current, and a drillstring that defines at least one path for a fluid flow to the bit to flush detached formation material from the borehole. A feed pipe transports at least a part of said fluid flow to said path, and the feed pipe is equipped with a cooling mechanism to cool the fluid flow. The use of a cooled fluid flow may enhance the performance of the pulsed-electric drilling process.

A method for managing a drilling operation, including generating, by a first sensor and a second sensor of a bottom hole assembly (BHA), a first time based data log and a second time based data log, respectively, representing a borehole parameter along a drilling trajectory, determining, by a computer processor of the BHA and during the drilling operation, a time shift by comparing the first time based data log and the second time based data log, where offsetting the first and second time based data logs by the time shift maximizes a correlation factor of the first and second time based data logs, and determining, within a pre-determined time period from generating the first and second time based data logs, a drilling speed based on the time shift and a pre-determined distance between the first sensor and the second sensor.

Apparatus and method for automated drilling of a borehole in a subsurface formation. In one embodiment, a method includes selecting at least one control variable. A drilling performance objective having a value that is influenced by drilling of the borehole using the at least one control variable is defined. A first interval of the borehole is drilled maintaining the at least one control variable at a first value. A second interval of the borehole is drilled maintaining the at least one control variable at a second value. A third interval of the borehole is drilled maintaining the at least one control variable at a third value. The third value is selected based on a comparison of the values of the drilling performance objective while drilling the first interval and second interval to a predetermined optimal value of the drilling performance objective.

Methods and apparatus are described to drill and complete wellbores. Such wellbores include extended reach horizontal wellbores, for example in shales, deep subsea extended reach wellbores, and multilateral wellbores. Specifically, the invention provides simple threaded subassemblies that are added to existing threaded tubular drilling and completion equipment which are used to dramatically increase the lateral reach using that existing on-site equipment. These subassemblies extract power from downward flowing clean mud, or other fluids, in an annulus to provide additional force or torque on tubular elements within the wellbore, while maintaining circulation, to extend the lateral reach of the drilling equipment and completion equipment. These added elements include combinations of The Leaky Seal™, a Cross-Over, The Force Sub™ and The Torque Sub™. The use of such additional simple elements allow lighter drilling equipment to be used to reach a given lateral distance, therefore reducing drilling costs.

Method and apparatus for controlling rock drilling with a percussion device belonging to a rock drill to deliver stress waves to rock through a tool by pushing the tool against the rock by means of a feed motor and rotating simultaneously the tool by means of a rotation motor, whereby the maximum feed force is determined, pressure medium is supplied to the feed motor and to the rotation motor and the feed force is controlled according to the drilling conditions. The feed force is controlled on the basis of the feed speed and the rotation torque. The apparatus has a load control valve which controls the feed.

Nozzles for drilling tools, such as rotary-type drag bits and roller cone bits, a drilling tool and drilling assembly comprising nozzles, and methods of conveying drilling fluid through a nozzle for use in drilling subterranean formations are provided. A nozzle may include a substantially cylindrical nozzle body having an axis and an inlet port with a primary passage extending therethrough, and at least one secondary passage that diverges from the primary passage at an exit port.

An adjustable bent drilling tool capable of changing in situ drilling direction to facilitate horizontal drilling. The drilling tool may be controlled from the surface and eliminates the need to bring the tool to the surface for reconfiguration. In one embodiment, the drilling tool utilizes a communications module to communicate with upstream sections of the tool. The communications module is connected to a programmable electronic control module which controls an electric motor. A hydraulic valve assembly follows the control module, which receives input signals and controls a pilot piston between two fixed points of a mid-assembly typically located adjacent to and downstream of the hydraulic valve assembly on the drill tool. A lower assembly is attached to the drill tool immediately following the mid-assembly, and provides both a safety release sub-assembly as well as a bendable sub-assembly which directs the adjustable drill tool to change drilling angle and direction.

A rotary joint for use in directional control of a subterranean rotary steerable drilling apparatus. The rotary joint is formed by mated spherical-shaped sockets, each of which is connected with a hollow rod. By virtue of this arrangement, a continuous passageway is provided for fluid to flow through the rotary joint, which fluid may be used for cooling the rotary joint during operation of the rotary steerable drilling system.

A down-hole hammer comprising a drill bit (10) and a drive collar (11) with an interconnection therebetween for causing rotation of the drill bit upon rotation of the drive collar. The drill bit (10) comprises a drill bit head (13) and a shank (19), the drill bit head (13) defining a cutting face (15) and having a circumferential shoulder section (17) adjacent the cutting face (15). The shank (19) extends from the shoulder section (17) in the direction away from the cutting face (15). The interconnection between the drill bit (10) and the drive collar (11) comprises a spline assembly including at least one spline (43) on the shoulder section (17) for mating engagement with at least one counterpart spline (63) on the drive collar (11) to provide a drive coupling therebetween while also allowing the drill bit (10) to slide axially within the drive collar (11) to perform a percussive action.

An apparatus for preparing drilled needle blanks from a spool of coiled stock wire may include a laser for drilling a bore in the end of the stock wire and a cutting device for cutting the drilled wire into needle blanks.

A method of stress relieving drilled surgical needles is disclosed. At least the metal about a drilled bore hole is heat treated to relieve stress without annealing.

Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles. Optional further improvement of the heat resistance and environmental resistance of said particles via post-polymerization heat treatment; processes for the manufacture of said particles; and use of said particles in the construction, drilling, completion and/or fracture stimulation of oil and natural gas wells are described.

A method may include determining a first particle size distribution for particulate additives in a first wellbore fluid circulated through a wellbore through an earthen formation, and determining a second particle size distribution for drilled cuttings resulting from drilling of the wellbore. The first and second particle size distributions may then be compared to determine a third particle size distribution for the combined particulate additives and the drilled cuttings. A lost circulation material having a fourth particle size distribution may then be selected based on the third particle size distribution and the selected lost circulation material may be pumped into the wellbore.

A method and a device for enabling the use of riserless drilling fluid recovery from a seabed-based borehole (1) which is to be drilled by means of a casing (26), the casing (26) being provided with a drill bit (28) at its lower portion and with an inner wellhead (30) at its upper portion, and there being a conductor casing (6), which has an outer wellhead (8), in the seabed (2), the method including: —providing a suction module (12) with a dividable adapter (16) which fits complementarily in the outer wellhead (8); —drilling a length of the borehole (1) by means of the casing (26) extending through the suction module (12), while, at the same time, drilling fluid is flowing via the suction module (12) from the borehole (1); —subsequently pulling the adapter (16) up from the outer wellhead (8) and dividing the adapter (16); and—lowering the casing (26) with the inner wellhead (30) through the suction module (12) and the adapter (16) to its position in the outer wellhead (8).

The present invention is a fence stay drill bit used along with a drill to install and uninstall fence stays more efficiently. The present invention further encompasses a method of installing and uninstalling fence stays using the present invention. The present invention has a drill bit extrusion and an elongated body which houses a slot and a recess. In the preferred embodiment, the elongated body has a cylindrical body which is a safety feature in preventing the present invention from accidentally attaching itself onto objects in the surrounding during use. The elongated body is also attached to a large fillet and a stay receiving lip. Both the recess and the stay receiving lip help guide a tip of a fence stay into the slot therein. The slot has a cavity which traps and stabilizes the tip of fence stay while the present invention is rotated by the drill.

Systems and methods for rig assembly and for erecting a mast of a rig and such systems with roller apparatus to facilitate movement of a mast section from a mover. In a first embodiment, the method includes erecting a rig mast section on a substructure, the substructure including a first substructure box spaced-apart from a second substructure box, the first substructure box comprising a first upper box above a first lower box and the second substructure box comprising a second upper box above a second lower box.

The present invention relates to a system and a method for the extraction of hydrocarbons from drill cuttings in drilling mud. The system for extracting hydrocarbons from drill cuttings includes at least one extraction tank, a carbon dioxide tank fluidly connected to the at least one extraction tank, and at least one separation tank in fluid communication with the at least one extraction tank. The method for extracting hydrocarbons from drill cuttings consists of exposing the drill cuttings to liquid carbon dioxide, solubilizing hydrocarbons from the drill cuttings with the liquid carbon dioxide, heating the liquid carbon dioxide and the soluble hydrocarbons to convert liquid carbon dioxide to carbon dioxide vapor, separating the hydrocarbons from the carbon dioxide vapor, and collecting the separated hydrocarbons.

A method for assembling a structure is described. The method includes locating a position in an assembly stack-up where a one-sided fastener is to be installed, drilling a hole through the assembly stack-up at the position, countersinking the hole to a specified depth, operating a calibrated probe to determine at least parameter associated with one or more of the hole and the stack-up proximate the hole, inserting the one-sided fastener into the hole, applying a rotational torque to the one-sided fastener to complete installation of the one-sided fastener, and comparing a measurement of angular displacement required to complete installation of the one-sided fastener to a range of angular displacement indicative of correct installation of the fastener.

Disclosed is a drillship having a vortex suppression block with a recessed flow stabilizing part in a moon pool. The flow stabilizing section is formed so that a bottom of the vortex suppression block that protrudes from a bottom of a hull toward a stern in the moon pool is recessed in an upward direction of the hull to stabilize a flow in the moon pool and reduce a variation in resistance of the drillship. The flow stabilizing section (30) is formed by partly recessing the bottom of the vortex suppression block toward an upper portion of the hull. The drillship having this configuration provides resistance performance improvement and flow stabilization of the drillship.

Systems and methods for separating fluids from drill cuttings. Specifically, the invention relates to shakers that incorporate a vacuum system and methods of operating such systems to effect a high degree of fluid separation. The system and methods are effective across a variety of screen sizes, vacuum flows and vacuum designs.

A drilling tool for machine tools has a drill body and a cutting head arranged on the front face of the drill body. The drill body has at least two chip flutes, which are delimited at their flanks by ribs and at least one of which is spirally curved. Arranged in the ribs of the drill body are coolant channels, which have an outlet opening at the end of the drill body on the cutting head side. A special feature is that the outlet openings are arranged within each one of the chip flutes and communicate with one of the coolant channels arranged in the ribs by way of a straight channel endpiece.

Earth-boring tools include a body, one or more blades projecting outwardly from the body, and cutting elements carried by the blade. The cutting elements include at least one shearing cutting element and at least one gouging cutting element. Methods of forming an earth-boring tool include mounting a shearing cutting element comprising an at least substantially planar cutting face to a body of an earth-boring tool, and mounting a gouging cutting element comprising a non-planar cutting face to the body of the earth-boring tool. The gouging cutting element may be positioned on the body of the earth-boring tool such that the gouging cutting element will gouge formation material within a kerf cut in the formation material by the shearing cutting element, or between kerfs cut in the formation material by a plurality of shearing cutting elements.