Abstract: The present invention relates to an aerial ladder truck to allow the height of a rear end of an extensible ladder, which is a connection end thereof connected at the rear of a bed of the truck, to be freely adjusted so that articles may be loaded in a space below the extensible ladder and above the truck bed.

Abstract: An apparatus for mounting an X-ray device or other electronic device, or a PAN disrupter or other mechanical device onto a ladder, the apparatus broadly comprising a horizontally extending mounting plate, a horizontally extending engagement bracket, a vertically extending mounting plate, and a hinge. The horizontally extending mounting bracket and the horizontally extending engagement bracket each include a rung engagement tab. The horizontally extending engagement bracket is slidable in relation to the horizontally extending mounting bracket for securing the apparatus to a ladder rung via the rung engagement tabs. The horizontally extending mounting plate stabilizes the electronic or mechanical device via the ladder rung and the vertically extending mounting plate supports the weight of the electronic or mechanical device on a lower ladder rung. The hinge pivotably connects the horizontally extending mounting plate and the vertically extending mounting plate.

Abstract: A drill string suitable for use in directional drilling of a borehole, comprising a rotatable shaft at the leading end of which is a drill bit, and wherein the shaft comprises a variable friction inducing member, which provides rotational friction by physical contact with an inside face of the borehole, the friction inducing member being arranged to exert a first rotational frictional force when the shaft in the vicinity of the member is substantially rotating and a second rotational frictional force when the shaft in the vicinity of the member is substantially not rotating, wherein the first rotational frictional force is less than the second rotational frictional force.

Abstract: The present disclosure provides a drill drive unit and drill string make up and break up unit with a method for use with a dual pipe drill string configuration. The drill drive unit is mounted to a single carriage and includes an outer drive spindle in a position fixed to the carriage with inner drive spindle configured to rotate independent of the outer drive spindle while being able to move longitudinally at least 12 inches relative to the outer drive spindle. The method involves connecting and disconnecting inner shafts and outer shafts of the dual pipe drill string.

Abstract: An apparatus for use in a horizontal section of a drill string is disclosed. The apparatus includes a motor that is connected to the horizontal section of the drill string. The motor is adapted to impart vibrations in the horizontal section of the drill string, where the vibrations are at about the lateral resonant frequency of the horizontal section of the drill string.

Abstract: A superabrasive compact and a method of making the superabrasive compact are disclosed. A superabrasive compact may comprise a superabrasive volume and a substrate. The substrate may be attached to the superabrasive volume via an interface. The superabrasive volume may be formed by a plurality of polycrystalline superabrasive particles. The superabrasive particles may have nano or sub-micron scale surface texture.

Abstract: A method for making a polycrystalline diamond compact including the step of providing a polycrystalline diamond compact. The compact has a substrate of a hard metal composition of material and a volume of diamond material disposed on the substrate. The diamond material includes a mixture of diamond particles and a binder-catalyst. At least one pre-coating layer of organic material impermeable to a given acid or mixture of given acids is applied to at least an exterior surface of the substrate. At least one layer of primer material that is impermeable to a given acid or mixture of given acids is applied on the at least one pre-coating layer. A layer of top coating material that is impermeable to the given acid or mixture of given acids is applied to the at least one primer layer.

Abstract: Cutters for a drill bit wherein the cutters have at least one groove in a face of a superabrasive table of the cutters. The cutters may also include ribs adjacent to the at least one groove.

Abstract: A roof-bolt drill bit includes a bit body that is rotatable about a central axis, a coupling pocket defined in the bit body, and at least one cutting element mounted to the bit body. The at least one cutting element includes a cutting face, a cutting edge adjacent the cutting face, a back surface opposite the cutting face, and a side surface extending between the cutting edge and the back surface. The roof-bolt drill bit additionally includes a coupling attachment coupled to the bit body, the coupling attachment being positioned adjacent to a portion of the side surface of the cutting element that abuts a side surface of the coupling pocket.

Abstract: A coring bit for extracting a sample of subterranean formation material from a well bore may include a bit body having a bit face and an inner surface defining a substantially cylindrical cavity of the bit body. A first portion of the inner surface may be configured to surround a core catcher. The coring bit may include a face discharge channel inlet formed in the inner surface of the bit body longitudinally at or above the first portion of the inner surface. The coring bit may also include a face discharge channel extending through the bit body from the face discharge channel inlet to the bit face. A tubular body having a core catcher may be disposed in the coring bit to form a coring tool. Methods of forming such bit bodies may include forming an inlet for a face discharge channel in the inner surface of the bit body at a location longitudinally at or above the first portion of the inner surface and forming a face discharge channel extending from the inlet to the bit face.

Abstract: Apparatus and methods related to riser joint connection are described. For example, some embodiments may contain a central coupler, a plurality of reaction collars, collar stoppers, collar caps, and C-rings, for connecting riser joints.

Abstract: In one embodiment, a wear band comprises a rotating element having a bore receivable on a tubular, the bore comprising first and second bore portions slidably receiving first and second sleeve bearings. Outer surfaces of the sleeve bearings slidably engage the bore portions and the bores of the sleeve bearings slidably engage the tubular. A first stop collar and a second stop collar may be received on the tubular to together straddle the rotating element and sleeve bearings to longitudinally secure the rotating element in a position on the tubular. The tubular may be included within a tubular string run into a borehole or into the bore of an installed casing, such as in casing while drilling. The rotating element provides stand-off between a tubular and the wall of a bore, reduces frictional resistance to longitudinal sliding and also to rotation of the tubular string within the bore.

Abstract: Apparatuses and methods to cut a control line and/or to run a control line on a rig may include a movable cutting apparatus to cut a control line, a load transfer member to engage a control line, a load measuring device to measure a load imparted to a load transfer member, and a drive member to engage and drive a control line. The apparatuses and methods may be used with a control line positioning apparatus, a pipe engaging apparatus, and/or may be used by themselves.

Abstract: A method and device for moving racked tubulars, such as pipe and casing joints on pipe racks at oil and gas well sites. The pipe moving tool comprises a wheel assembly with a long straight handle. The wheels fit inside the pipe, which is then moved by simply pushing or pulling the handle forward or backward, as needed. Several wheel assemblies of different diameters may be used interchangeably with a single handle. An extension handle also may be included. The use of this tool makes moving the pipe safer as the worker's hands are not exposed to injury. Additionally, the handle on the tool makes it possible to easily and more safely reach and move shorter pipes racked above or below longer pipes in a multi-level pipe rack; it is not necessary for the worker to lean over or under the longer pipes.

Abstract: A compensation and fill up assembly comprises a slip assembly for engaging a tubular and a compensation assembly for supporting a weight of the tubular when engaged by the slip assembly. The compensation and fill up assembly further comprises a fluid swivel and a fill up tool coupled to the fluid swivel by a fluid shaft. The fill up tool is insertable into and rotatable with the tubular using the fluid swivel.

Abstract: A rotary table has a non-circular drive recess in the central opening which carries an assembly of mounting structures and slip carriers that when joined together fit in the non-circular drive recess. The plurality of slip carriers are distributed about the periphery of the drive recess are extended down into the central opening of the rotary table. A slip and die arrangement is situated on each slip carrier. Slip manipulation drive cylinders, are distributed about the assembly periphery and move a synchronizer plate that moves the slips vertically to grip or release pipe extending through the opening of the rotary table.

Abstract: A system for facilitating the connection of a first tubular to a second tubular used in the oil and gas exploration and extraction industries includes a tubular handling device having a body having a profile shaped to accept a first tubular into a throat area and opposing scissor plates with overlapping tips. The system further includes a tubular engagement apparatus to engage and raise a tubular to a vertical position, and a spider apparatus including a plurality of slip assemblies. The slip assemblies include a slip back with an inclined load bearing surface, and a slip with a load bearing surface in sliding abutment with the inclined load bearing surface of the slip back.

Abstract: A modified filter screen for use in a downhole drilling operation is disclosed. The filter screen is able to be installed at the surface of a well, and is pin-loaded for easy access and maintenance. The modified filter screen may be retained within a section of pipe below the top drive above the rig floor by allowing dowel pins on the section of pipe to engage with latch slots on the filter screen. The modified filter screen may also be retained by engaging a threaded connector on the filter screen with a threaded connector on the interior of the section of pipe or by utilizing pins and/or retaining rings.

Abstract: A method and apparatus for drilling a wellbore is disclosed. The wellbore is drilled with a drill string that includes a bypass device having a fluid passage therethrough by supplying a fluid through the bypass device at a first flow rate, wherein the fluid circulates to a surface location via an annulus between the drill string and the wellbore. The flow rate of the fluid is altered to a second flow rate. A time period is defined and a mechanical motion of the bypass device is initiated. A parameter related to the mechanical motion of the bypass device and a parameter related to flow rate are detected. The bypass device is activated to divert a portion of the fluid to the annulus when the parameter related to mechanical motion is detected and the parameter related to flow rate is present during the defined time period.

Abstract: According to the method for well and reservoir management in open hole completions, a data acquisition module (100) is advanced through the wellbore and acquires data providing information revealing fractures in the wall of the wellbore, and at least one blocking system (1002, 3000), on the basis of the data acquired, is placed in the wellbore(199, 2199, 3006) at the location of a fracture in the wall. The data acquisition module (100) is advanced by interaction with a fluid present in the wellbore, and the data acquisition module acquires data providing information on its own position in relation to the wall (3005) of the wellbore (199, 2199, 3006) and is controlled on the basis of said data in order to maintain a distance to the wall of the wellbore during its advancement. A system for well and reservoir management in open hole completions is further disclosed.

Abstract: A tool retrieves material from a well. The tool has a cylindrical tool body, malleable members, and a cylindrical jacket. The tool body defines a chamber adapted to receive material for retrieval. The malleable members are on the lower end of the tool body and preferably are made of a relatively hard, tough malleable material such as steel. They are bendable from an open position allowing material to enter the chamber to a closed position capturing the material. The jacket is mounted on the exterior of the tool body and has a mill surface which is adapted to bend the malleable members from the open position to the closed position. Relative axial movement of the jacket and the tool body causes the malleable members to bear on the mill surface and bend to the closed position.

Abstract: A downhole tool comprises a housing having a longitudinal bore and an agitator assembly disposed within the longitudinal bore of the housing. A removable component is disposed within the longitudinal bore and can be removed from the housing so as to at least partially open the longitudinal bore.

Abstract: A wellhead hanger assembly is provided. In one embodiment, a system includes a wellhead hanger, such as a casing hanger. This system also includes a spacer ring positioned along a neck of the wellhead hanger between a threaded portion of the neck and a shoulder of the wellhead hanger. In at least some instances, the spacer ring may cooperate with a running tool threaded onto the wellhead hanger to reduce the break-out torque needed for disconnecting the running tool from the wellhead hanger. Additional systems, devices, and methods are also disclosed.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured valving member with curved and flat portions that alternatively direct fluid flow through a bore or opening in the valving member via an inner channel or around the periphery of the valving member in an outer channel. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members.

Abstract: A hydraulic cable injector includes a first stripper assembly positioned at a first end of the hydraulic cable injector to receive a cable and provide a lower seal. A first wye joint is coupled to the first stripper assembly, and a flow tube assembly is operatively coupled to the first wye joint. A second wye joint is coupled to the flow tube assembly, and a second stripper assembly is coupled to the second wye joint and proves an upper seal. A third stripper assembly is positioned at a second end of the hydraulic cable injector for injecting the cable into a tubing and providing a tubing seal. A separator interposes the second and third stripper assemblies and defines a central pathway to feed the cable into the third stripper assembly from the second stripper assembly.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method of treating a subterranean formation comprising: providing coated particles, wherein the coated particles comprise solid particles coated with an expandable coating; and introducing the coated particles into a permeable zone of the subterranean formation such that the coated particles form a barrier to fluid flow in the permeable zone. In another embodiment, a method of drilling a well bore may be provided, the method comprising: including coated particles in a drilling fluid, the coated particles comprising solid particles coated with an expandable coating; using a drill bit to enlarge the well bore; and circulating the drilling fluid past the drill bit.

Abstract: Various tools for locking components in place within a wellhead housing are provided. In one embodiment, a system includes a lockdown tool having an inner body, an outer body coupled to the inner body, and a locking mechanism carried by the inner body. The locking mechanism can be selectively engaged by moving the outer body with respect to the inner body to secure the lockdown tool to the wellhead housing. Additional systems, devices, and methods are also disclosed.

Abstract: A completions assembly that includes an extendable and retractable shifting tool at a lower end of an upper completion. Outfitted with this type of tool, the upper completion may be sealably landed out at an installed lower completion without prematurely opening an isolation valve that ensures well control thereat. Rather, the full completions assembly may be finished out and the valve later opened by extending of the shifting tool from the upper completion toward the isolation valve at the lower completion. Once more, this type of well control is achieved through use of hydraulic lines that are dedicated to the upper completion even though the isolation valve is located therebelow. As a result, the extended use of hydraulic couplings and other complex or wear-prone well control architecture may be largely avoided.

Abstract: A flow control system for use with a subterranean well can include a flow chamber through which a fluid composition flows, and a closure device which is biased toward a closed position in which the closure device prevents flow through the flow chamber. The closure device can be displaced to the closed position in response to an increase in a ratio of undesired fluid to desired fluid in the fluid composition. A structure can prevent the closure device from being displaced to the closed position. The fluid composition can flow through the structure to an outlet of the flow chamber.

Abstract: A multi-acting downhole tool arrangement (100), (400), (500) includes a tubular (102) and an actuatable sliding member (104), (404), (504) radially disposed relative to the tubular (102) in a radial sealing relationship. The tubular (102) and the member (104), (404), (504) are arranged relative to one another in a non-slidable first configuration. The sliding member (104), (404), (504) and the tubular (102) cooperate to define a chamber 116 therebetween. At least a pair of seals (108), (110), (410), (446) delimits the chamber (116). A first one (110), (446) of the pair of seals is a degradable seal. Upon actuation of the sliding member (104), (404), (504), the sliding member (104), (404), (504) slides in a first direction relative to the tubular (102) to a second configuration where the degradable seal (110), (446) is exposed to a condition that degrades the degradable seal (110), (446).

Abstract: A downhole flow control apparatus comprising: at least one tubular body (1) locatable at a zone of a well, the tubular body (1) having a longitudinal through bore and one or more transverse ports (5a, 5b) and a port covering device (3) which, in use, is movable from a lower position in which the or each port is covered to an upper position in which the or each port is open; and at least one plugging device (6) which is operable to travel downhole from the surface to locate within and seal the through bore of the tubular body, the plugging device including moving means (10) to cause the port covering device (3) to move from the lower position to the upper position thus allowing fluid communication between the through bore and the or each port (5a, 5b).

Abstract: A well tool having an actuator sleeve in a housing. The actuator sleeve has an internal shifting tool engaging profile. The tool has an actuator in the housing that is responsive to a remote signal to change from an unactuated state to an actuated state and shift the actuator sleeve from a first position to a second position. A fluid chamber in the housing is defined between the actuator sleeve and the actuator. The fluid chamber contains a fluid to communicate movement of the actuator to the actuator sleeve.

Abstract: Disclosed are wellbore flow control devices that allow on-site field adjustments to flow characteristics. One autonomous inflow control device (AICD) assembly includes a housing arranged about a base pipe that defines at least one flow port and an interior, the housing defining a fluid compartment in fluid communication with the at least one flow port, an AICD arranged in the fluid compartment and having at least one fluid inlet and an outlet in fluid communication with the at least one flow port, a shroud coupled to the housing and covering the fluid compartment, and a crimping tool arrangeable about the housing and the shroud and having a profile defined thereon, the profile being configured to engage and plastically deform the shroud in order to fluidly isolate the AICD.

Abstract: A fluid container reloading tool for a downhole fluid sampling tool is described. The reloading tool includes an elongated cylindrical body. The body may include a bottom opening sized to engage with a fluid sampling tool deployed within a borehole. A cache of empty fluid containers may be included within the body. A piston may be coupled to at least one of the fluid containers in the cache of fluid containers. The piston may be used to transfer the cache of fluid containers into the fluid sampling tool. The reloading tool may also include a pump in fluid communication with the piston.

Abstract: The present invention relates to an apparatus and a method for monitoring a hydrate decomposition area under different drilling and production processes.

Abstract: The present disclosure relates to a downhole rotating magnetic field generator, wherein a stator assembly is formed by fixedly connecting a guiding stator, windings, and a body together, and a rotor assembly is formed by mounting a turbine rotor and a permanent magnet together. Between the stator assembly and the rotor assembly, sliding bearings are arranged and small mud passages are formed. There is no metal isolation between the rotor and the stator for cutting through the magnetic lines of force, so that the eddy current loss is relatively small. Meanwhile, with mud flowing through the passages as lubricant, overheating of the generator can be prevented and high power output can be ensured.

Abstract: Planning lateral wellbores within irregular boundaries. At least some of the illustrative embodiments are methods including: logically dividing an irregular polygon into a plurality of contiguous sub-areas, the irregular polygon representing an outer boundary of mineral rights; planning a first plurality of layouts of lateral wellbores residing in a first sub-area, each layout along a distinct azimuthal direction; selecting a layout of the first plurality of layouts based on a selection criteria, the selecting creates a first selected layout; planning a second plurality of layouts of lateral wellbores residing in a second sub-area, each layout of the second plurality of layouts along a distinct azimuthal direction; selecting a layout of the second plurality of layouts based on a selection criteria, the selecting creates a second selected layout; creating an overall layout for the irregular polygon by combining the first and second selected layouts; and displaying the overall layout on a display device.

Abstract: A perforating tool usable in a well casing to perforate the well casing. Perforating tool includes an activation member disposed in body wherein the activation member is moveable relative to the body to move at least one working member between and inwardly retracted condition an outwardly deployed condition relative to the body. A plurality of pistons is arranged to move the activation member relative to the body, each piston being disposed in a respective pressure chamber arranged to be filled with fluid in response to an increase in fluid pressure in the body.

Abstract: A perforation tool assembly. The perforation tool assembly comprises a tool string connector, a perforation gun coupled to the tool string connector, and a structure configured to absorb mechanical energy released by firing one or more perforation guns. The coupling is configured to provide a limited range of motion of the tool string connector relative to the perforation gun. The tool string connector and the perforation gun retain the structure configured to absorb mechanical energy.

Abstract: A perforating gun that has a detonator section in which a window is formed is assembled by: disposing a detonating cord in an inner bore of the perforating gun; fixing a clip to a detonator; gripping the clip with an installation tool; inserting the clip laterally through the window of the detonator section using the installation tool; and attaching the clip to the detonator cord by pressing the clip against the detonator cord using the installation tool. The clip has a planar base, an opening formed in the base for receiving the detonator, and a pair of prongs extending from the base, wherein each prong of the pair of prongs extends from an edge of the base and has a gripping end.

Abstract: An igniter assembly is disclosed for initiating an explosive charge in a setting tool. In an embodiment, the igniter assembly includes a longitudinal axis, and a holder including a first end, a second end opposite the first end, and a through passage. In addition, the igniter assembly includes an igniter disposed within the through passage. The igniter comprises a single igniter system. Further, the igniter assembly includes a contact seal plug disposed at least partially within the through passage. The contact sealing plug is configured to sealingly engage the through passage to prevent fluid flow out of the through passage beyond the first end of the holder.

Abstract: A distributed artificial lift system is configured for use in a wellbore that includes a vertical section and at least one lateral section connected to the vertical section. The distributed artificial lift system includes a first remote assembly positioned within the first lateral section. The first remote assembly includes an equipment deployment vehicle and cargo selected from the group consisting of electric remote pumping units, tubing, tubing connectors, tubing adaptors, sensor packages, gas separators, perforating tools, injection pumps and other downhole components. The first remote assembly is optionally self-propelled and remotely-controlled.

Abstract: A method for enhanced oil recovery in an underground reservoir involving use of system including at least one injection well having an injection pump for establishing an injection stream, the injection pump includes a carrier system and an enzyme system; at least one production well having at least one fluid output; a mixed injection stream through the at least one injection well including a first injection stream having a flow rate S1 produced by the carrier system and a second injection stream having a flow rate S2 produced by the enzyme system; a concentration of enzyme Cen,3 in the mixed injection stream established using the formula C en , 3 = ( C en , 1 · S 1 + C en , 2 · S 2 S 1 + S 2 ) , where Cen,1 and Cen,2 are the enzyme concentration of the first and second injection streams; and an underground water stream in fluid connection with the injection well and production well, the stream including water injected by the carrier system and enzyme solution injected

Abstract: A system for in-situ heating of a subsurface formation for the extraction of hydrocarbons in underground deposits is disclosed. The system is configured to heat the underground deposit of hydrocarbons to facilitate fluid flow and hydrocarbon recovery from the underground deposit. The system has an antenna formed from a coaxial transmission line having an annular space between the transmission line outer conductor and the inner conductor and having one or more periodic aperture arrangements along the axial length of the outer conductor. A method for in-situ heating of a subsurface formation for recovering hydrocarbons contained therein is also disclosed. The method comprises: providing an antenna in the subsurface formation; providing electromagnetic RF power to the antenna for heating at least a portion of the subsurface formation.

Abstract: A method of gas production from a field containing natural gas processing particularly for transport of stranded gas to conserve resources and reduce emissions includes extracting gas a gas supply from a plurality of individual gas wells in the field and initially at the individual gas wells providing a recovery unit having a production capacity matching that of the well for carrying out liquid recovery from the gas supply and compression of the natural gas. When a production rate of the well declines to a low level, typically to about 20% of the original, the recovery unit is removed for redeployment either at a central plant or at other wells which are still at the high production and is substituted by a dehydration system and gas compressor arranged to fill portable pressure vessels typically on trucks for transporting the compressed natural gas to a main pipe line.

Abstract: Methods and systems for controlling drilling operations include using a statistical model to identify at least two controllable drilling parameters having significant correlation to one or more drilling performance measurements. The methods and systems further generate operational recommendations for at least two controllable drilling parameters based at least in part on the statistical model. The operational recommendations are selected to optimize one or more drilling performance measurements.

Abstract: An earth-boring drilling tool comprises a cutting element. The cutting element comprises a substrate, a diamond table, and at least one sensing element formed from a doped diamond material disposed at least partially within the diamond table. A method for determining an at-bit measurement for an earth-boring drill bit comprises receiving an electrical signal generated within a doped diamond material disposed within a diamond table of a cutting element of the earth-boring drill bit, and correlating the electrical signal with at least one parameter during a drilling operation.

Abstract: A system to create a surface log by using a processor connected to data storage on a network that creates and executive dashboard of surface log information using computer instructions to (a) form an editable surface log template, (b) import user information, well sensor information, well event based observation data; well fluid testing data, (c) scale the imported data, forming scaled values, (d) computing a microview and a macroview log plot using the scaled values; (e) creating an executive dashboard, (f) inserting the log plots onto the executive dashboard and other real time well logging information allowing viewing of the log plots simultaneously with the other information on a real time basis, enabling safety interpretations for drilling, geological interpretations for drilling, operational interpretations for drilling, and combinations of these interpretations, in real time.

Abstract: Disclosed are systems and methods of observing downhole tool operations through surface monitoring of vibrations. One system includes at least one downhole tool arranged within conveyed into a wellbore on a work string of a well and configured to facilitate at least one downhole event that generates at least one shock wave, the wellbore including a wellhead, one or more sensors arranged at or near a surface of the well the wellhead and configured to sense the one or more shock waves generated by the at least one downhole tool, and a computer system configured to receive and process sensor signals from the one or more sensors and generate a resulting output signal corresponding to the downhole event.

Abstract: An apparatus for retaining electronic components in a downhole component coupling mechanism includes: a power supply frame including a first housing configured to retain a power supply therein and isolate the power supply from downhole fluids, the power supply frame configured to be disposed in and constrained axially by a coupling assembly of a first downhole component and a second downhole component; an electronic component disposed in a second housing in the coupling assembly, the electronic component located external to the power supply frame; and a connector configured to transmit electric power from the power supply to the electronic component to supply electrical power to the electronic component.