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Realtime dogleg severity prediction

Tue, 26 May 2015 08:00:00 EDT

A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.



System and method for stick-slip correction

Tue, 26 May 2015 08:00:00 EDT

A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth.



Rotary drag bit

Tue, 26 May 2015 08:00:00 EDT

A rotary drag bit has one or more fixed composite cutting structures formed from a plurality of discrete prefabricated cutters that abut each other along complementary side surfaces, the composite cutting structure being placed and oriented on the cutting face of the rotating body so that the composite cutting structure presents a cutting profile that does not expose any portion of the cutting face that is between or behind the composite cutting structure, with respect to the direction of travel of the composite cutting structure during boring, to the uncut earth formation as the body is rotated during boring.



Down-hole hammer drill

Tue, 26 May 2015 08:00:00 EDT

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.



Rotary joint for subterranean drilling

Tue, 26 May 2015 08:00:00 EDT

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.



Tools for use in subterranean boreholes having expandable members and related methods

Tue, 26 May 2015 08:00:00 EDT

Expandable apparatus for use in subterranean boreholes include at least one member configured to move between a retracted position and an extended position. Components of the expandable apparatus may include at least one surface for removing debris proximate to the tubular body. Components of the expandable apparatus may be configured to enable the expandable apparatus to increase a diameter of a subterranean borehole by greater than twenty percent. Components of the expandable apparatus may be configured to restrict fluid flow to nozzle assemblies. The expandable apparatus may include a protect sleeve having a push sleeve disposed therein. Methods of operating an expandable apparatus may include removing debris with a surface of the expandable apparatus. Methods of operating an expandable apparatus may also include selectively flowing fluid to nozzle assemblies.



Tools for use in subterranean boreholes having expandable members and related methods

Tue, 26 May 2015 08:00:00 EDT

Expandable apparatus for use in subterranean boreholes include at least one member configured to move between a retracted position and an extended position. A latching member disposed in the tubular body may selectively retain the at least one member in the retracted position. Methods of operating an expandable apparatus include securing at least one member of the expandable apparatus in a retracted position by engaging an inner wall of a tubular body with at least one latch member disposed in at least one aperture formed in a latch sleeve.



Adjustable bent drilling tool having in situ drilling direction change capability

Tue, 26 May 2015 08:00:00 EDT

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.



Method for determining wellbore position using seismic sources and seismic receivers

Tue, 26 May 2015 08:00:00 EDT

A method for determining position of a wellbore in the Earth's subsurface includes actuating a plurality of seismic energy sources each disposed at a known geodetic position. Seismic energy from the sources is detected at a selected location along the wellbore. The geodetic position at the selected location is determined from the detected seismic energy. A corresponding method includes actuating a seismic energy source at a selected position within the wellbore. The seismic energy is detected at a plurality of known geodetic positions. The geodetic position of the source is determined from the detected seismic energy.



Method and device for riserless drilling fluid recovery

Tue, 26 May 2015 08:00:00 EDT

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).



Reconfigurable cement composition, articles made therefrom and method of use

Tue, 26 May 2015 08:00:00 EDT

A pourable aqueous cement composition is disclosed. The cement composition comprises a hydraulic cement, water and a selectively removable material comprising a plurality of selectively corrodible metal powder particles dispersed within the cement or a nanomatrix powder compact, or a combination thereof. An article, including a downhole article, and more particularly a reconfigurable downhole article is disclosed. The article includes a hydraulic cement, wherein the hydraulic cement has at least partially set into a permanent form. The article also includes a selectively removable material dispersed within the cement, the selectively removable material comprising a plurality of selectively corrodible metal powder particles dispersed within the cement or a nanomatrix powder compact, or a combination thereof, wherein the selectively removable material is configured for removal in response to a predetermined wellbore condition.



Apparatus for creating and customizing intersecting jets with oilfield shaped charges

Tue, 26 May 2015 08:00:00 EDT

A geological perforating tool (gun) shape charges disposed at an angle that provides an improvement over other known embodiments by accurately securing the charges in the tool to facilitate reliable, reproducible focus of the shaped charges. Charges are disposed on metal strips fitted into slots that are precision cut at predetermined angles in a tool barrel circumference.



Spacer fluid additive

Tue, 19 May 2015 08:00:00 EDT

A spacer fluid comprises a fluid and a viscosity agent. The viscosity agent is a mixture of at least two polyvinylalcohol compositions. A first polyvinylalcohol composition comprises polyvinylalcohols having a first degree of hydrolysis and a second polyvinylalcohol composition comprises polyvinylalcohols having a second degree of hydrolysis. The first and second degrees of hydrolysis are substantially different such that the rheology of the spacer fluid is stable during temperatures changes.



Methods for improving thermal stability of silicon-bonded polycrystalline diamond

Tue, 19 May 2015 08:00:00 EDT

Methods for preparing a silicon bonded PCD material involving a one step, double sweep process and drilling cutters made by such processes are disclosed. The PCD material includes thermally stable phases in the interstitial spaces between the sintered diamond grains. The method sweeps a diamond powder with a binder to form sintered PCD, reacts said molten binder with a temporary barrier separating said binder and said diamond from a silicon (Si) source, and sweeps said sintered PCD with said Si source to form SiC bonded PCD.



Rolling cutter

Tue, 19 May 2015 08:00:00 EDT

A cutting element for a drill bit includes an outer support element and an inner rotatable cutting element, a portion of which is disposed in the outer support element, where the inner rotatable cutting element has a body with a non-planar cutting face.



High-shear roller cone and PDC hybrid bit

Tue, 19 May 2015 08:00:00 EDT

A drill bit having a bit body, at least one blade extending radially from the bit body, a plurality of blade cutting elements disposed on each blade, at least one journal extending downwardly and radially outward from a longitudinal axis of the drill bit, a roller cone or roller disc mounted rotatably to each journal, and a plurality of cutting elements disposed on each roller cone or roller disc, and methods for making the drill bit are disclosed.



Hammer bit

Tue, 19 May 2015 08:00:00 EDT

A hammer bit includes a bit body coupled to a hammer drill, a housing bit disposed to the bit body, at least one wing bit coupled to the housing bit to move up and down slantly, and having a rotating radius that is more increased than an outer surface of the bit body when moving up and is more decreased than the outer surface of the bit body when moving down, and at least one spacer installed to move up and down together with the wing bit and filling up an upper space of the wing bit when the wing bit moves down.



Vibrational tool with rotating engagement surfaces and method

Tue, 19 May 2015 08:00:00 EDT

A vibrational tool and method is disclosed, which may be utilized to assist in lowering a drill string into a wellbore. In one embodiment, a reciprocating member and a symmetrical rotating member are mounted within a vibrational tool housing. The reciprocating member is urged in one embodiment by a spring assembly toward the rotating member whereby engagement surfaces on the reciprocating member and rotating member encounter each other. As the rotating member rotates, variable surfaces on the engagement surface cause the reciprocating member to reciprocate as the variable surfaces follow or cam with respect to each other during rotation. The resistance to rotation by engagement surfaces and spring assembly, and mass of the rotating member, result in vibrational forces, when drilling fluid flows through the vibration tool housing.



Nozzles including secondary passages, drill assemblies including same and associated methods

Tue, 19 May 2015 08:00:00 EDT

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.



Method and apparatus for controlling rock drilling

Tue, 19 May 2015 08:00:00 EDT

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.



Method and system for monitoring a well for unwanted formation fluid influx

Tue, 19 May 2015 08:00:00 EDT

A method of monitoring a well for unwanted formation fluid influx is disclosed. Measurements of well outflow are acquired during a period in which drilling operations are performed for the well. Occurrences of stagnant flow events during the period are determined. An outflow signature is generated from the well outflow measurements for each stagnant flow event. The outflow signatures are displayed sequentially in time of occurrence. Each outflow signature is analyzed for an anomaly.



Method and system for delineating a second wellbore from a first wellbore

Tue, 12 May 2015 08:00:00 EDT

Disclosed herein is a method of delineating a second wellbore from a first wellbore. The method includes, emitting acoustic waves from a tool in the first wellbore, receiving acoustic waves at the tool reflected from the second wellbore, and determining orientation and distance of at least a portion of the second wellbore relative to the tool.



Polycrystalline diamond compact including a polycrystalline diamond table containing aluminum carbide therein and applications therefor

Tue, 12 May 2015 08:00:00 EDT

Embodiments of the invention relate to polycrystalline diamond compacts (“PDCs”) comprising a polycrystalline diamond (“PCD”) table including at least a portion having aluminum carbide disposed interstitially between bonded-together diamond grains thereof, and methods of fabricating such PDCs. In an embodiment, a PDC includes a substrate, and a PCD table bonded to the substrate. The PCD table includes a plurality of bonded-together diamond grains defining a plurality of interstitial regions. The PCD table further includes aluminum carbide disposed in at least a portion of the plurality of interstitial regions.



Custom shaped blank

Tue, 12 May 2015 08:00:00 EDT

A blank may include a tang section, a base section, and an angled section with a recess. The tang section may have an outer surface with an outer diameter. The base section may have an outer surface with a diameter greater than the outer diameter of the tang section. The angled section may lie between the tang section and the base section and may have an outer surface that transitions in diameter from the outer diameter of the tang section to the outer diameter of the base section. The recess in the angled section may be shaped to engage a tip of a former.



Universal drilling and completion system

Tue, 12 May 2015 08:00:00 EDT

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 of completing a well using a friction reducing completion fluid

Tue, 12 May 2015 08:00:00 EDT

A method for reducing the friction forces between tubulars, for example coiled tubing in casing includes mixing a selected suspending agent and surfactant and polymer particles in oil, then adding the mixture to water and pumping the mixture down the tubing. The mixture is particularly useful in coiled tubular drilling inside casing of an oil or gas well. The formulation has also been found to reduce corrosion on metal surfaces.



Apparatus and method for automated drilling of a borehole in a subsurface formation

Tue, 12 May 2015 08:00:00 EDT

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.



Drilling speed and depth computation for downhole tools

Tue, 12 May 2015 08:00:00 EDT

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.



Cooled-fluid systems and methods for pulsed-electric drilling

Tue, 12 May 2015 08:00:00 EDT

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.



Control system for high power laser drilling workover and completion unit

Tue, 12 May 2015 08:00:00 EDT

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.



Structure for gunpowder charge in combined fracturing perforation device

Tue, 12 May 2015 08:00:00 EDT

This invention provides a structure for gunpowder charge for charging gunpowders of different rates in combined fracturing perforation devices. The structure for gunpowder charge is convenient to mount and transport. In one embodiment, said structure for gunpowder charge comprises an inner gunpowder box located between adjacent perforating charges in the charge frame of a perforation device, and an outer gunpowder box attached to the outer wall of the charge frame, wherein said outer gunpowder box comprises one or two box units (2 or 4) with at least one claw at the inner side of said box unit, said claw can be locked into a groove or installation hole of the charge frame, and wherein said inner gunpowder box and said outer gunpowder box are charged with gunpowders of different burning rates.



Remote control system for drill

Tue, 05 May 2015 08:00:00 EDT

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.



Systems and methods for processing drilling data

Tue, 05 May 2015 08:00:00 EDT

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.



Active compensation for mud telemetry modulator and turbine

Tue, 05 May 2015 08:00:00 EDT

An arrangement having a piston configured to move along an axial pathway a rotating seal configured to seal an inside environment from an outside environment, the rotating seal configured to be acted upon by a pressure exerted from the piston, a differential pressure sensor measuring a pressure difference between a first fluid from the outside environment and a second fluid on the inside environment, a motor connected to the piston, the motor configured to actuate the piston to a position along an axial pathway and an electronic feedback control system connected to the motor, the electronic feedback system configured to interface with the differential pressure sensor and maintain a pressure generated by the piston onto the rotating seal to a desired pressure.



Dust collecting attachment

Tue, 05 May 2015 08:00:00 EDT

It is an object of the invention to provide a technique that contributes to rationalization of dust collection, in a dust collecting attachment for use on a power tool. Dust collecting attachments 250, 350 are used on a power tool 201 having a tool body 203, a tool bit 209 which can be coupled to a front end region of the tool body 203, and an auxiliary handle 208 attached to the tool body 203. The dust collecting attachments 250, 350 include dust collecting members 251, 351, respectively, which can be attached to the auxiliary handle 208 in such a manner as to surround the front end region of the tool body 203 around a longitudinal axis of the front end region in order to collect dust generated during operation by the power tool 201, and a connecting hose 273 for connecting the dust collecting members 251, 351 to a dust collector.



Shaped cutting elements for earth-boring tools, earth-boring tools including such cutting elements, and related methods

Tue, 05 May 2015 08:00:00 EDT

A cutting element for an earth-boring tool. The cutting element comprises a substrate base, and a volume of polycrystalline diamond material on an end of the substrate base. The volume of polycrystalline diamond material comprises a generally conical surface, an apex centered about a longitudinal axis extending through a center of the substrate base, a flat cutting surface extending from a first point at least substantially proximate the apex to a second point on the cutting element more proximate a lateral side surface of the substrate base. Another cutting element is disclosed, as are a method of manufacturing and a method of using such cutting elements.



Diamond bonded construction comprising multi-sintered polycrystalline diamond

Tue, 05 May 2015 08:00:00 EDT

Diamond bonded constructions comprise a diamond body attached to a substrate, wherein the body includes a first diamond bonded volume, and a second diamond bonded volume attached thereto. The second volume may be provided in the form of a powder or a presintered mass prior to attachment, and the first volume may be provided in the form of presintered pieces when combined with the second volume. The first volume diamond volume content is greater than about 94 percent, and is the same or greater than that of the second volume. The first volume is sintered during a first HPHT process, and the second volume is sintered and/or attached to the first volume during a second HPHT process. The first HPHT pressure is greater than the second HPHT pressure. The substrate is not an infiltration substrate used to form the first diamond volume. The diamond body may be thermally stable.



Drilling fluid that when mixed with a cement composition enhances physical properties of the cement composition

Tue, 05 May 2015 08:00:00 EDT

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.



Reverse circulation apparatus and methods of using same

Tue, 05 May 2015 08:00:00 EDT

In one aspect, an apparatus for drilling a wellbore into an earth formation is disclosed, which apparatus, according to one embodiment, may include a drill string configured to be conveyed into a wellbore, wherein an annulus is formed between the drill string and a wellbore wall, a first flow device configured to circulate a first fluid from an annulus to a bore of the drill string, and a second flow device positioned downhole of the first flow device, the second flow device configured to circulate a second fluid from the bore of the drill string to the annulus.



Vibration detection in a drill string based on multi-positioned sensors

Tue, 05 May 2015 08:00:00 EDT

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.



Drill bit assembly having electrically isolated gap joint for measurement of reservoir properties

Tue, 05 May 2015 08:00:00 EDT

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.



Wear indicators for drilling equipment

Tue, 05 May 2015 08:00:00 EDT

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.



Method and apparatus for opening threaded joints of drilling equipment

Tue, 05 May 2015 08:00:00 EDT

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.



Directional drilling attitude hold controller

Tue, 05 May 2015 08:00:00 EDT

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.



Methods and systems for improved drilling operations using real-time and historical drilling data

Tue, 05 May 2015 08:00:00 EDT

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.



Gas cutting borehole drilling apparatus

Tue, 05 May 2015 08:00:00 EDT

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.



One trip casing or liner directional drilling with expansion and cementing

Tue, 05 May 2015 08:00:00 EDT

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.



Automated well control method and apparatus

Tue, 28 Apr 2015 08:00:00 EDT

A drilling control system monitors and compares drilling and completion operation sensor values and autonomously acts in response to conditions such as a kick or surge. Sensors in various combinations may monitor return fluid flow rate, fluid inflow rate, wellhead bore pressure, temperature of returning fluid, torque, rate of penetration and string weight change. The control system has corresponding control logic to monitor, warn and act based on the sensor inputs. The actions may include the warning of support personnel, closing an annular blowout preventer, shearing drill pipe using a ram shear, pumping heavier fluid down choke and kill lines, disconnecting the riser or various other actions.



Ruggedized tool and detector device

Tue, 28 Apr 2015 08:00:00 EDT

A tool comprising a tool body having an opening defined by interior walls extending into the tool body and a casing disposed within the opening. The tool further includes a scintillator material disposed within the casing and a first compressive member disposed within the tool body at a first axial location. The first axial location extends for a fraction of a total axial length of the casing and exerts a first radially compressive force at the first axial location.



Rolling cutter placement on PDC bits

Tue, 28 Apr 2015 08:00:00 EDT

A cutting tool cutting tool may include a tool body having a plurality of blades extending radially therefrom; and a plurality of rotatable cutting elements mounted on at least one of the plurality of blades, wherein the plurality of rotatable cutting elements are mounted on the at least one blade in a nose and/or shoulder region of the cutting tool at a side rake angle ranging from about 10 to about 30 degrees or −10 to about −30 degrees.