Abstract: A slip component for a downhole tool has a bearing surface hard surface treated. The slip component, which can be a slip or other component of a slip mechanism used on a packer, bridge plug, or other downhole tool, is composed of a metallic base material such as magnesium, aluminum, an aluminum alloy, or a magnesium alloy. To hard surface treat the slip component, at least the bearing surface is positioned relative to an electro sparking apparatus. Using the electrosparking apparatus, an external layer is bonded at least on the bearing. In a further embodiment, an intermediate layer can be first bonded onto at least the bearing surface by ion sputtering an intermediate material onto the metallic base material of the slip component. Then, an external layer can be bonded at least on the intermediate layer by electrospark deposition.

Abstract: An apparatus for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein is provided. The apparatus includes a radio frequency (RF) antenna configured to be positioned within the wellbore, a transmission line configured to be positioned in the wellbore and coupled to the RF antenna, and an RF source configured to be coupled with the transmission line. The transmission line includes at least one transmission line tuning section including an inner conductor, an outer conductor surrounding the inner conductor, and a liquid-blocking plug between the inner and outer conductors to define a tuning chamber configured to receive a dielectric liquid with a gas headspace thereabove.

Abstract: An apparatus is provided for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein. The apparatus includes a radio frequency (RF) source, an RE antenna configured to be positioned within the wellbore, and an RF transmission line configured to be positioned within the wellbore and couple the RE source to the RE antenna. The RE transmission line defines a liquid coolant circuit therethrough. The apparatus further includes a liquid coolant source configured to be coupled to the transmission line and to provide a liquid coolant through the liquid coolant circuit having an electrical parameter that is adjustable.

Abstract: An apparatus is provided for heating a hydrocarbon resource in a subterranean formation having a wellbore extending therein. The apparatus includes a radio frequency (RF) antenna configured to be positioned within the wellbore, a transmission line configured to be positioned in the wellbore and coupled to the RF antenna, and an RF source configured to be coupled to the transmission line. The apparatus also includes a balun configured to be coupled to the transmission line adjacent the RF antenna within the wellbore. The balun comprises a body defining a liquid chamber configured to receive a quantity of dielectric liquid therein.

Abstract: Acoustic radiators for coal bed methane or shale gas production are configured to be strategically placed on drillstrings within gas production exhaust boreholes and hydraulically powered so they will radiate intense harmonic sonic waves to shake the solid media immediate to the wall areas. The gas volume output that can be realized by an exhaust well depends highly on the permeability of the media, especially at inside faces of the borehole. The shaking half-opens up fractures and pores in the solid media. Thus the permeability of the media to gas improves under such shaking and gas collection efficiencies are improved. The beneficial effects can be increased by locating two or more acoustic radiators proximate to one another in a phased relationship.

Abstract: A shockwave generator pre-treats one or more production zones within a well to facilitate recovery of liquid and gaseous hydrocarbons from the well. The well may be heated to a particular temperature, where after a cooling agent is introduced through the shockwave generator which effects a cooling action in the walls of the well and induces cracking which is propagated by the tremors or shocks of the cooling agent as it exits the generator. The initiated cracks may be further propagated using one or more additional stimulation methods, including a freeze-thaw method which is implemented through a subsystem having overlapping components with the shockwave generator subsystem.

Abstract: A method for determining a volume of a fracture network includes detecting seismic signals deployed over an area of the subsurface during pumping of fracturing fluid into at least one wellbore drilled through the area. A hypocenter of each fracture induced by the pumping is determined using the seismic signals. A facture network and associated fracture volume is determined using the determined hypocenters and seismic moments determined from the detected seismic signals. A maximum value of a scaling factor is determined based on a subset of the hypocenters having a highest cumulative seismic moments. The scaling factor is determined by relating a pumped volume of the fracturing fluid with respect to the determined fracture volume. Dimensions of each fracture are scaled using the maximum value of the scaling factor. The fracture volumes are recalculated using the scaled dimensions.

Abstract: The methods described are for determining distribution, orientation and dimensions of networks of hydraulically-induced fractures within a subterranean formation containing fluids. Micro-seismic events are generated, after cessation of fracturing and establishment of fracture networks, by particles introduced into the fractures which are capable of explosive or chemical reaction. In one method, attachment site particles are positioned within the formation during fracturing and additional reactive particles are later introduced. The reactive particles attach to the attachment sites and, upon a triggering event, react to produce micro-seismic events. The waves generated by the micro-seismic events are used to provide mapping of the effective fracture space. Additionally, time-lapse mapping is provided with use of “species” of attachment sites and reactive particles.

Abstract: A method for conveying logging tools (LT) and obtaining well log data from a wellbore is disclosed. The method includes running a drill string (DS) including a landing sub (LS) disposed near the lower end into a wellbore. A logging tool string (LTS) is inserted into the upper end of the DS bore. A fluid is pumped into the upper end of the DS bore to assist movement of the LTS. As the fluid is pumped behind the LTS, the cable at the surface is spooled out and the fluid pressure is monitored. The landing assembly of the LTS is landed in the LS. A diagnostic test is activated and run to determine proper functioning of the LT. A release mechanism releases the running tool portion of the LTS. The cable is spooled in. The drill pipe string is pulled upward in the wellbore as the LT are recording data.

Abstract: The present disclosure describes a system, method and computer readable medium capable of dynamically managing a hydrocarbon recovery operation. The hydrocarbon recovery operation may utilize an injection well and a production well. Proportional integral derivative controller(s) may be utilized to control injection processes (for the injection well) and/or production processes (for the production well) using temperature and/or pressure data obtained from the formation. One or more production tubulars may be equipped with inflow control devices capable of controlling the flow of hydrocarbons from the formation into the production well. In one embodiment, the PID controller(s) may adjust the positioning of the injection tubing strings and/or production tubulars within their respective wells. A graphic user interface may be provided to allow users to adjust and/or customize recovery operation parameters.

Abstract: A method of controlling fluid flow into a heavy oil production pipe includes reducing inflow into the production pipe locally from hot spots using inflow control devices including a movable body provided within a housing, the movable body being arranged to adjust the flow of fluid through the inflow control devices autonomously by exploiting the Bernoulli principle; increasing inflow into the production pipe remote from the hot spots using the inflow control devices to increase inflow locally; and increasing draw down in the production pipe by using an injector to inject a gaseous medium at or downstream of the inflow control devices.

Abstract: A method for locating casing collars in a cased wellbore includes moving a well logging instrument coupled within a drill string through the cased wellbore. The instrument includes at least one electromagnetic transmitter and at least two spaced apart electromagnetic receivers. The at least one electromagnetic transmitter is energized with alternating current. A phase difference between electromagnetic signals detected by each of the at least two electromagnetic receivers is measured. A position of at least one casing collar is determined when a change in the measured phase shift is detected.

Abstract: Example embodiments of the present disclosure are directed to measurement and control systems and methods of improved spooling accuracy. Specifically, the systems and method disclosed herein provide techniques for accurately monitoring the depth of a sandline in a wellbore through sensing spool rotation, and controlling certain aspects of the spooling and/or producing certain notifications when the depth is above or below a certain threshold. Thus, the spool can be operated with increased diligence when it gets close to the wellhead. In certain example embodiments, the depth of the sandline is measured based at least partially on the number of spool rotations, compensating for decreasing length of sandline per layer of sandline on the spool.

Abstract: A system includes a regional blending facility having a number of bulk receiving facilities, where each bulk facility receives and stores a particle type having a distinct size modality, a bulk moving device that transfers particles between the bulk receiving facilities and of a blending/continuously receiving vessel and/or a mixer, and a carrying medium vessel. The mixer receives particles from the blending/continuously receiving vessel and/or the bulk moving device, receives a carrying medium from the carrying medium vessel, mixes the particles with the carrying medium, and provides a mixed treatment fluid. The system includes a fluid conduit that fluidly couples a wellsite location with the regional blending facility, where the fluid conduit delivers the mixed treatment fluid to the wellsite and/or delivers produced fluid from a wellbore positioned at the wellsite to the regional blending facility.

Abstract: An injector insert apparatus is provided. The injector insert apparatus includes a body that has an inner oil passage that is configured and arranged to allow oil to pass there through. The body further has an annular chamber formed around the inner oil passage. The annular chamber has a chamber opening that is configured to be coupled to receive a flow of thermal gas medium. The body also has at least one injector orifice that provides a passage between the annular chamber and the inner oil passage. The at least one injector orifice is configured to inject the thermal gas medium into oil passing through the inner oil passage.

Abstract: Solvent may be injected into a hydrocarbon reservoir at an increasingly elevated vertical level to allow vapor of the solvent to contact and mobilize viscous hydrocarbons in the reservoir, for producing mobilized hydrocarbons. Solvent may be injected into a mobile zone below a viscous hydrocarbon zone, to allow solvent vapor to ascend to mobilize viscous hydrocarbons in the viscous hydrocarbon zone. A vertical or slanted injection well may be used to inject the solvent into the reservoir, and a production well spaced horizontally apart from the injection well may be used to produce fluids from the reservoir. A bottom-up solvent-aided process may comprise injecting water and liquid solvent into the mobile zone, and then injecting heated water and solvent into the mobile zone.

Abstract: Thermal recovery of oils is improved by capturing waste heat from a depleted steam chamber using steam plus foam and an optional gas to carry low quality steam deep into the chamber where the waste heat converts water to steam in situ. Thus, overall steam generation needs and thus costs are reduced.

Abstract: A borehole is drilled from the surface to an underground shale matrix. A pipe is inserted into the borehole. Openings are created in the pipe in fluid communication with fractures in the shale matrix. The interior surface of at least one section of pipe is coated with a contaminant-capturing substance. Fracturing fluid including water, proppants and chemicals is pumped through the pipe and into the fractures in the shale matrix. The fluid re-enters the pipe from the shale matrix and moves toward the surface through the coated pipe section where contaminants are sequestered by the coating. Natural gas or oil from the fractured shale then enters the pipe and moves to the surface to be collected. The coated pipe section remains in the ground permanently such that the necessity of disposing of the captured contaminants is eliminated.

Abstract: An ultra-lightweight, high strength ceramic proppant made from mixture of naturally occurring clays, preferably porcelain clay, kaolin and/or flint-clay, earthenware clay or other naturally occurring clays having an alumina content between about 5.5% and about 35%. The proppant has an apparent specific gravity from about 2.10 to about 2.55 g/cc, and a bulk density of from about 1.30 to about 1.50 g/cc. This ultra-lightweight proppant is useful in hydraulic fracturing of oil and gas wells, and has greater conductivity than sand at pressures up to 8,000 psi as measured by Stim-Lab after 50 hours and 275° F. on Ohio Sandstone, in the presence of deoxygenated aqueous 2% solution of KCI.

Abstract: A floating apparatus for use in a casing string is provided. The apparatus includes an outer sleeve having a valve centrally positioned therein. A cement body is affixed to the check valve and the housing by use of a bonding material.

Abstract: A method of inhibiting an undesirable fluid flow path, including pumping a flow of fluid downhole, the flow of fluid containing a plurality of shape-change particles; depositing the shape-change particles in an undesirable fluid flow path in a downhole structure; transitioning the shape-change particles from a first shape to a second shape; forming a plug with the shape-change particles when in the second shape; and inhibiting the undesirable fluid flow path from fluid flow therethrough with the plug of shape-change particles.

Abstract: In some general aspects, methods for intersecting a first, cased well bore include drilling a second well bore that has a distal end proximal to the first, cased well bore to be intersected, disposing a mill guiding device in the second well bore near a casing of the first, cased well bore, the mill guiding device being configured to direct a mill of a milling assembly away from a central axis of the second well bore and towards the first, cased well bore, inserting the milling assembly into the second well bore, operating the mill of the mill assembly and guiding the milling assembly along the mill guide and into the casing of the first well bore, and removing material from the casing of the first well bore until the first, cased well bore and the second well bore are fluidly connected.

Abstract: A well is drilled and casing installed utilizing a casing drilling technique. A bottom hole assembly having a drill bit and a fluid diverter is secured to a string of drill pipe and installed within a casing string. Drilling fluid is pumped down the drill pipe string to cause the drill bit to rotate and drill the well while the fluid diverter is in a drilling mode position. At the total depth for the casing string, the operator moves the fluid diverter to a cementing position and pumps cement down the drill pipe and up the casing string annulus. After cementing, the operator moves the fluid diverter to a packer set position and again pumps drilling fluid down the drill string to set the packer.

Abstract: Disclosed herein are cement compositions and methods of using set-delayed cement compositions in subterranean formations. In one embodiment a method of plugging a wellbore is described. The method comprises providing a set-delayed cement composition comprising pumice, hydrated lime, a cement set retarder, and water; activating the set-delayed cement composition to produce an activated set-delayed cement composition; introducing the activated set-delayed cement composition into the wellbore; and allowing the activated set-delayed cement composition to form a plug in the wellbore that has a permeability of less than 0.1 millidarcy.

Abstract: This disclosure is related to downhole tool having an erosion resistant material metalurgically bonded to portions of the downhole tool. The downhole tool can have the erosion resistant material can be disposed on predetermined portions of inner and outer surfaces of the downhole tool. The disclosure is also related to a method of using the downhole tool described herein.

Abstract: The invention concerns bifunctional compositions usable in the field of extraction of hydrocarbons, oil and/or gas, said compositions being homogeneous, clear and stable and comprising at least one anti-mineral-deposit additive, at least one corrosion inhibitor, and at least one agent for compatibilizing between the anti-mineral-deposit additive and the corrosion inhibitor.

Abstract: A method of treating a well including the steps of: (A) treating a first aqueous fluid comprising seawater with electrocoagulation to obtain a second aqueous fluid, wherein the second aqueous fluid has a reduced concentration of magnesium ions relative to the original concentration of magnesium ions in the first aqueous fluid; (B) forming a treatment fluid comprising: (i) an aqueous phase, wherein the aqueous phase comprises the second aqueous fluid, and (ii) a viscosity-increasing agent in the aqueous phase; and (C) introducing the treatment fluid into a well. The aqueous phase can have a pH of at least about 9 or the treatment fluid can be introduced into a well at a design temperature of at least about 93° C. (200° F.).

Abstract: Apparatus and methods for conducting well-related fluids are disclosed. The apparatus and methods may be used to mitigate erosion of fluid handling equipment by fluids associated with hydrocarbon wells. An exemplary apparatus comprises: an upstream conduit including an upstream fluid passage for receiving and conducting well-related fluid; a choke member including a choke fluid passage; and a downstream conduit including a downstream fluid passage in fluid communication with the upstream fluid passage via the choke fluid passage. A cross-sectional area of the downstream passage may be greater than a cross-sectional area of the upstream passage to allow expansion of the fluids passing through the choke such that the average velocity of such fluids may not exceed a threshold velocity selected to mitigate erosion of the downstream conduit.

Abstract: An apparatus comprises a telescoping marine riser action and one of a rotating control device and an annular blow out preventer. The telescoping marine riser section comprises an inner barrel and an outer barrel.

Abstract: In some embodiments, apparatus useful for providing tubing into an underwater well includes at least one surface injector and at least one underwater injector. The surface injector is adapted and arranged to control the movement of the tubing into and out of the underground well below the sea floor during normal operations. At least one surface injector and/or underwater injector is arranged and adapted to maintain the tubing in substantial tension between the surface and underwater injectors.

Abstract: The disclosed hydrocarbon lift system and method prohibits water-coning in production of oil from a subterranean reservoir to the earth's surface. The system comprises a well bore with a first and a second section. The first section has perforations which draw a first fluid into and up the well bore based on a negative pump pressure applied thereto. The second section has perforations which draw a second fluid into the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein. The system also comprises a venturi structure fixtured into the well bore. The venturi structure has flaring ends connected by a constricting throat defining perforations therein. The constricting throat perforations draw the second fluid through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an increased first fluid velocity there through.

Abstract: An apparatus for controlling a flow of a fluid between a wellbore tubular and a formation may include a frac tool having at least one port in selective fluid communication with the formation, and an inflow control device having a flow control path configured to provide a predetermined pressure drop for a flowing fluid. The inflow control device may have a flow coupler configured to provide selective fluid communication with the at least one port.

Abstract: The present invention relates to an annular barrier to be expanded in an annulus between a well tubular structure and an inside wall of a borehole for providing zone isolation between a first zone and a second zone of the borehole, comprising a tubular part for mounting as part of the well tubular structure and having an expansion opening, an expandable sleeve surrounding the tubular part, each end of the expandable sleeve being connected with the tubular part, and an annular barrier space between the tubular part and the expandable sleeve, wherein the annular barrier further comprises a pressure intensifying means having an inlet in a first end in fluid communication with the expansion opening and having an outlet in a second end in fluid communication with the annular barrier space.

Abstract: A rupture disc assembly and a float tool incorporating the rupture disc assembly is disclosed. The rupture disc assembly may include a rupture disc assembly comprising a rupture disc, an upper tubular portion and a lower tubular portion, and a securing mechanism for holding the rupture disc between the upper and lower tubular portions. A float tool for creating a buoyant chamber in a casing string may include the rupture disc assembly and a sealing device for sealing the lower end of the casing string, the buoyant, sealed chamber may be created there between. In operation, applied fluid pressure causes the rupture disc to move downward. The rupture disc may be shattered by contact with a surface on the lower tubular portion. Full casing internal diameter may be restored in the region where the rupture disc formerly sealed the casing.

Abstract: The invention concerns a method for installing an apparatus for monitoring physical parameters in an annulus of an oil and/or gas well having a well head. The apparatus comprises a sensor plug including a sensor and a flange assembly arranged with a bore holding a signal processing unit for communication with the sensor. The method comprises the following steps; installing the sensor plug including the sensor in a passage in the well head, which passage communicates with an annulus of the well, connecting a cable connector to the sensor plug, which cable connector is attached to an end of a cable, connecting the sensor of the sensor plug to the signal processing unit in the bore of the flange assembly, positioning the bore of the flange assembly essentially coinciding with the passage of the well head thereby inserting the cable connector into the bore and attaching the flange assembly to the well head thereby.

Abstract: A method includes running an assembly on a tool in a contracted state into a well. The assembly includes segments that are adapted to be radially contracted and arranged in a first number of layers along a longitudinal axis of the assembly in the contracted state of the assembly. The technique includes using the tool to expand the assembly downhole in the well to transition the assembly between the contracted state and an expanded state. Using the tool to expand the seat assembly includes radially expanding the segments and longitudinally contracting the segments to arrange the layers in a second number of layers having at least one layer less than the first number.

Abstract: A technique that is usable with a well includes deploying a seat assembly into a tubing string; releasing the seat assembly at a downhole location inside the tubing string; pumping the seat assembly to a restriction in the tubing string at a second downhole location; and using an untethered object received in a seat assembly to form an obstruction in the tubing string.

Abstract: Disclosed are downhole subassembly systems and method of use thereof. One downhole subassembly system is an orientable whipstock subassembly that includes a whipstock apparatus including a deflector surface operable to direct a cutting tool into a casing sidewall to create a casing exit, and an orienting sub comprising an upper coupling operatively coupled to the whipstock apparatus and a lower coupling at least partially engaged with the upper coupling and rotationally movable with respect thereto while in an un-collapsed configuration and rotationally fixed with respect thereto while in a collapsed configuration.

Abstract: A downhole activation assembly for activating a downhole component of a downhole tool positionable in a wellbore penetrating a subterranean formation. The activation assembly includes a housing operatively connectable to the downhole tool, a spring-loaded sleeve, and a ball catcher. The sleeve slidably positionable in the housing, and having a flow channel therethrough and an outer surface defining a chamber between the sleeve and the housing. The sleeve having inlets therethrough about a sleeve end thereof to permit fluid from the flow channel to pass therethrough. The ball catcher slidably positionable in the housing, and having a catcher end engageable with the sleeve end to selectively divert the fluid thereabout and a ball seat therein to receivingly engage a ball passing through the sleeve whereby the ball catcher selectively moves the downhole component between activation positions.

Abstract: One disclosed sleeve assembly disposed within a base pipe includes a first sleeve portion having a first shear resistance for resisting movement of the sleeve assembly with respect to the base pipe, and a second sleeve portion moveable with respect the first sleeve portion and having a second shear resistance for resisting movement of the second sleeve portion with respect to the first sleeve portion, the second shear resistance being greater than the first shear resistance.

Abstract: A wellbore ball valve includes a ball-type valve closure having an interior, central bore. A lower ball carrying assembly defines a first annular, sealing seat surface in contact with and adapted to seal with the exterior of the valve closure. The first seat surface defines a first through hole. An upper assembly defines a second annular seat surface in contact with the exterior of the valve closure. The second seat surface defines a second through hole. The second through hole is shaped differently from the first through hole in that it at least partially overlaps with the central bore while the first through hole is sealed from the central bore.

Abstract: A hydraulically set packer has a mandrel with an internal bore and a port communicating the internal bore outside the mandrel. A packing element disposed on the mandrel can be compressed by a piston to engage the borehole. The piston is disposed on the mandrel on a first side of the packing element and moves against the packing element when tubing pressure is communicated into a first piston chamber via the mandrel's port. To increase the setting forces, a sleeve disposed between the packing element and the mandrel defines a space communicating an opposite side of the packing element with a second pressure chamber of the piston. During high pressure operations, high pressure on the first side of the packing element acts with high pressure on the first side of the piston, increasing the pistons movement from a high pressure region to a low pressure region.

Abstract: The fire sprinkler system of the preferred embodiments is preferably installed in a space defined by two beams, such as rafters, extending along the width of a space and separated by a distance equal to a length of the space. The fire sprinkler system includes a supply line generally extending along the width of the space and generally located between the rafters, and a series of sprinklers connected to the supply line. Each sprinkler is adapted to disperse in a coverage area having a length and a width, which is substantially less than the length. Each sprinkler is oriented such that the length of each coverage area extends in opposite directions toward the rafters. The fire sprinkler system may also be installed in a space having a series of purlins extending the length of the space. In this variation, each sprinkler is located between two purlins.

Abstract: A portable fire extinguisher includes a housing (3) and a cartridge (4) arranged within the housing (3). The cartridge (4) is fixedly connected at a bottom thereof to the housing (3) via a fastening device (40). This on the one hand facilitates shifting, and on the other hand allows the cartridge (4) to be fixed appropriately in the housing (3), thus not easily rotated or loosened, also, the need of a production site for waiting for silicone solidification by standing for seven to eight hours is avoided when silicone injection for fixing is used, thus improving production efficiency.

Abstract: Disclosed is a portable fire extinguishing device, which comprises a casing (1) and a cartridge (2) provided inside the casing (1). The device is characterized in that: the casing (1) comprises a first half casing (4), a second half casing (5) fitted to the first half casing (4), a fastening ring (6) and a bottom cover (7); the first half casing (4) and the second half casing (5) are butted; the fastening ring (6) is provided on the top ends of the first half casing (4) and the second half casing (5) so as to fasten the both; and the bottom cover (7) is provided at the bottoms of the both. The first half casing, the second half casing, the fastening ring and the bottom cover are clamped and fixedly connected with each other to form a whole casing so that the whole wall thickness of the casing is uniform, thus improving injection moulding processes, reducing the difficulty in manufacturing a mould, saving plastic resources, and facilitating installation and disassembly.

Abstract: The present patent application relates to a fire fighting apparatus comprising an ergonomic setting for simple, fast and safe handling during supply and use even under the most adverse conditions.

Abstract: A fire protection device including a frame having a body with an inlet and an outlet disposed spaced along a longitudinal axis of a passageway. A pair of arms is disposed in a first plane parallel to the longitudinal axis and coupled to the body. A deflector assembly having a generally planar face portion is distally spaced from the outlet of the body and orthogonal to the longitudinal axis. The face portion includes two openings on opposite sides of a second plane perpendicular to the first plane. A canopy portion is supported on a first side of the first plane from the face portion. The deflector assembly includes a plurality of tines extending along the face portion on a second side of the first plane. Each of the tines have an outer edge disposed on a common circle centered along the longitudinal axis.

Abstract: Compositions are described which are useful in many applications such as fire extinguishing or refrigeration. The compositions may include a hydrochlorofluorocarbon such as 2,2-dichloro-1,1,1-trifluoroethane, a dispersant such as CF3I, and an inert gas such as argon, and may in some embodiments be held under pressure. For example, some fire extinguishing compositions may be composed of 2,2-dichloro-1,1,1-trifluoroethane, CF3I, and argon.

Abstract: An agricultural row unit assembly includes an attachment frame configured for attachment to a tow bar that is movable in a direction of travel. A proximal end of a swing-arm is coupled to the attachment frame, and an opener disk is mounted to and offset from a distal end of the swing-arm for forming a furrow. The opener disk is configured to rotate about a first axis relative to the direction of travel. A deflecting disk is mounted to the distal end for deflecting debris from entering the furrow, and is mounted between the distal end of the swing-arm and the opener disk. The deflecting disk is configured to rotate about a second axis, which is different than the first axis, relative to the direction of travel. A closing wheel is coupled to the attachment frame for closing the furrow.

Abstract: A fastening device may include a fastening tool body having a fastener on one end; a drive unit installed on the fastening tool body and providing fastening power to the fastener; a gyroscopic sensor that is installed on the fastening tool body and detects the displacement of the fastening tool body and outputs a detection signal thereof; an angle sensor that detects the angle of the fastening tool body and outputs a detection signal thereof to a controller; and the controller that receives the signals output from the gyroscopic sensor and the angle sensor and output a set actuating signal to the drive unit.