Abstract: A downhole rotational rate control apparatus is disclosed, adapted for coupling to the lower end of a drill string, and includes a progressive cavity (PC) pump or motor, multiple fluid flow paths, and a flow control valve for controlling fluid flow in the flow paths. Drilling mud flowing downward through the drill string is partially diverted to flow through the PC pump or motor and, in turn, the PC pump or motor speed is controlled by the flow control valve. The control valve can be actuated by a control motor in response to inputs from a sensor assembly in an electronics section. The PC pump or motor drives a controlled downhole device at a specific zero or non-zero rotational rate. By varying the rotational rate of the PC pump or motor relative to the rotational rate of the drill string, the tool face orientation or non-zero rotational speed of the controlled device in either direction can be varied in a controlled manner.

Abstract: A portable mast assembly is comprised of a skid assembly having a horizontally oriented frame comprised of longitudinally extending support beams and a mast assembly having at least two vertically extending columns that are supported directly upon a longitudinally extending mast beam without an intervening track or roller. A means for moving the mast beams along the top of the extending support beams of the frame without a roller is provided.

Abstract: Methods produce hydrocarbons from an unconventional reservoir using a number of sidetrack lateral wells. A first of the lateral wells is drilled and produced before being closed for drilling of a subsequent lateral well. Drilling and production from such horizontal laterals alternates between first and second mother wellbores. One mother wellbore thereby undergoes drilling and completion while the other mother wellbore is in production.

Abstract: A downhole intelligent reamer controller detects the difference between rotary drilling and sliding drilling, responds appropriately and quickly to multiple changes between rotary drilling and sliding drilling that may occur several times each stand of pipe. Additional controls prevent deployment of reamer members at inappropriate times such as when drilling out cement, testing, and running in and out of the wellbore. In one embodiment, a separate modular control sub is disclosed that may be utilized with and/or removably secured to an expandable reamer and/or other types of downhole tools.

Abstract: An earth-boring tool includes a cutting element having a first volume of polycrystalline material including catalyst material and a second volume free of catalyst material. A boundary between the first volume and the second volume is nonlinear in a cross-sectional plane that includes a centerline of the cutting element and an anticipated point of contact of the cutting element with the surface of the formation to be cut. Each line tangent the boundary in the cross-sectional plane forms an angle with the centerline of the cutting element greater than the contact back rake angle of the cutting element. In some cutting elements, some portions of the boundary may have another selected shape. Some cutting elements have a boundary wherein tangent lines form angles of greater than 20° with the centerline of the cutting element. Methods of forming wellbores are also disclosed.

Abstract: Passive load balancing in a fluid bearing for a rotational device is provided using disclosed devices, systems, and methods. In particular, fluid bearing apparatus may include an outer member with an inner member disposed concentrically within the outer member. A fluid inlet may provide fluid communication with a surrounding space between the inner and outer members. A bearing may be connected to the inner member and may extend into the surrounding space. The apparatus may also include a piston located in the surrounding space between the bearing and the fluid inlet. A supporting fluid is located between the piston and a surface of the bearing to transmit force from the piston to the bearing.

Abstract: Methods and systems for delivery and retrieval of fluids to and from a downhole location are disclosed. A dual string pipe (202) is provided which comprises an outer pipe (206), an inner pipe (204) positioned within the outer pipe, and a bottom hole assembly (210) fluidically coupled to the outer pipe and the inner pipe. A diverter sub (208) is coupled to the inner pipe and is selectively operable in a normal drilling mode and a high flow mode. In the normal drilling mode a fluid is directed downhole through the inner pipe and in the high flow mode a return fluid is directed uphole through the inner pipe.

Abstract: A method of forming a set grout includes steps of preparing a grout additive fluid comprising a fresh water base fluid and a grout additive control package comprising a primary additive selected from the group consisting of an inhibitor, a dispersant, a thermally conductive material, and any combination thereof; introducing an aqueous swellable clay into the grout additive fluid, thereby forming a final grout fluid; and introducing the final grout fluid into an annulus in a subterranean formation, the annulus formed between an exterior of a geothermal well loop tubular and the subterranean formation. The ordering of additives in the method results in enhanced effectiveness of the additives, which may reduce the amount of additive loading required.

Abstract: A fluid pulse apparatus for down hole drilling having a turbine assembly actuated by a flow of drilling fluid. The apparatus has a narrowed fluid flow section that cooperates with a piston that moves between an open and a fluid flow restricting position. The apparatus has a turbine assembly that rotates in response to a flow of drilling fluid. The turbine apparatus has upper and lower cam surfaces that cooperate with fixed cam followers such that rotation of the turbine assembly and cam action between the cam surfaces and the fixed followers causes the turbine assembly to reciprocate axially. The piston is fixed to either of the upper or the lower cam surfaces such that as the turbine assembly reciprocates axially, the piston moves between the open and the flow restricting positions to create a pulsed fluid flow.

Abstract: A polycrystalline diamond element leaching assembly includes a polycrystalline diamond element, a protective leaching cup surrounding at least a portion of the polycrystalline diamond element, and a protective layer positioned between the polycrystalline diamond element and the protective leaching cup. A method of processing a polycrystalline diamond element includes covering a selected portion of a polycrystalline diamond element with a curable resin layer, curing the curable resin layer to form a protective layer, and exposing at least a portion of the polycrystalline diamond element to a leaching agent. Another method of processing a polycrystalline diamond element includes depositing a curable resin within a protective leaching cup and positioning a polycrystalline diamond element within the protective leaching cup such that the curable resin is displaced so as to surround at least a portion of the polycrystalline diamond element.

Abstract: A method for selecting a drill bit, the method including selecting a first drill bit design, simulating the first drill bit design drilling an earth formation under selected conditions, graphically displaying at least a portion of the simulating, analyzing results of the simulating, wherein the analyzing comprises reviewing a steerability of the first bit design, selecting a second drill bit design, simulating the second drill bit design drilling an earth formation under selected conditions, graphically displaying at least a portion of the simulating, analyzing results of the simulating, wherein the analyzing comprises reviewing a steerability of the second bit design and selecting, based upon the analyzing, a bit design is disclosed.

Abstract: A longer-lasting, lower cost, more powerful, all metal, mud motor than the presently available progressing cavity type mud motors for drilling boreholes into the earth. A mud motor apparatus possessing one single drive shaft that turns a rotary drill bit, which apparatus is attached to a drill pipe which provides high pressure mud to the mud motor, wherein the drive shaft receives at least a first portion of its rotational torque from any high pressure mud flowing through a first hydraulic chamber within the apparatus, and receives at least a second portion of its rotational torque from any high pressure mud flowing through a second hydraulic chamber within the apparatus. The mud motor apparatus possesses two hydraulic chambers, each having its own power stroke, and return stroke, and acting together in a controlled fashion, provide continuous power to a rotary drill bit.

Abstract: A motor control apparatus includes a motor, a motor controller, and a connection line. The motor is mounted to a vehicle and has a metal housing. The motor controller is separately provided with the motor, includes a housing and a circuit portion, is connected to the motor through a load line, and drives the motor by a drive current transmitted through the load line. A ground line of the circuit portion is connected to a body of the vehicle as a body earth. The connection line directly connects the metal housing of the motor and the circuit portion of the motor controller without through the housing of the motor controller.

Abstract: An apparatus for use in resonance enhanced rotary drilling. The apparatus comprising one or both of: (a) a vibration isolation unit; and (b) a vibration transmission unit. The vibration isolation unit and/or the vibration transmission unit typically comprising a spring system comprising two or more frusto-conical springs arranged in series.

Abstract: A pneumatically operated vertical clam shell mud bucket attaches to a pipe joint connection in a drill stem on a drilling rig, the mud bucket defining a first tubular section forming a half cylinder hingably attaching a second tubular section forming a mirror image half cylinder, the tubular sections forming a sealed cylinder which is forcibly closed together by a plurality of pneumatic cylinders with a composition compression material forming a liquid seal between the closed half cylinders containing drilling fluids during the drilling stem separation and connection diverting drilling fluids to an outer evacuation hose to an external recirculating system on the drilling rig.

Abstract: A portable mast assembly is comprised of a skid assembly having a horizontally oriented frame comprised of longitudinally extending support beams and a mast assembly having at least two vertically extending columns that are supported directly upon a longitudinally extending mast beam without an intervening track or roller. A means for moving the mast beams along the top of the extending support beams of the frame without a roller is provided.

Abstract: Earth-boring tools may comprise a body comprising a first region and a second region. The first region may be located closer to a rotational axis of the body than the second region. A first cutting element may be located in the first region and a second cutting element may be located in the second region. A first polycrystalline table of the first cutting element may be substantially free of catalyst material to a first depth and a second polycrystalline table of the second cutting element may be substantially free of catalyst material to a second, greater depth.

Abstract: A method for determining a drilling state of a bottom hole assembly in a wellbore includes acquiring one or more downhole sensor measurements and processing the sensor measurements using a downhole processor to determine a drilling state of the bottom hole assembly. An operating state of the bottom hole assembly may be automatically changed in response to the determined drilling state. A method for computing a dynamic drilling energy of a bottom hole assembly includes acquiring at least one sensor measurement and processing the sensor measurements to obtain at least one of (i) an energy of axial motion of the bottom hole assembly, (ii) an energy of rotational motion of the bottom hole assembly, and (iii) an energy of lateral motion of the bottom hole assembly.

Abstract: A downhole drilling motor comprises a first elastomer stator molded to an inner surface of a housing in a drillstring where the first elastomer stator has a first number of lobes. A dual purpose, helical shaped hollow member is positioned within the first elastomer stator, where the dual purpose hollow member has a second number of lobes formed on an external surface to form a first rotor. The second number of lobes is one less than the first number of lobes. A second elastomer stator is adhered to an inner surface of the dual purpose helical shaped hollow member, where the second elastomer stator has a second helical shaped cavity with the second number of lobes. A second helical shaped rotor is positioned within the second helical cavity, and has a third number of lobes one less than the second number of lobes.

Abstract: Apparatus for drilling and lining a wellbore is described herein. A method of drilling and lining a wellbore is also described herein. A liner hanger is provided, secured in use on a liner. The liner hanger is operable selectively to be set and unset. The liner hanger is adapted to support the liner within an existing casing when set and to release the liner from the casing when unset. A liner hanger setting tool is provided, secured in use on a drill string. The liner hanger setting tool is actuatable selectively to set and unset the liner hanger. The liner hanger setting tool is operable selectively to be activated and deactivated. The liner hanger setting tool is adapted to attach to the liner and/or liner hanger when activated, to support the liner, and to release from the liner and/or liner hanger when deactivated.

Abstract: A coring assembly comprises an outer barrel coupled to a coring bit. An inner barrel is disposed within the outer barrel. An inner sleeve is disposed within the inner barrel and includes at least one frangible region that allows the inner sleeve to break so that coring operations can continue after the occurrence of a core jam.

Abstract: An underreamer for increasing a diameter of a wellbore. The underreamer includes a body having an axial bore extending at least partially therethrough. A mandrel is disposed within the bore of the body and has a port formed radially therethrough. A sleeve is disposed radially-outward from the mandrel. The sleeve blocks fluid flow through the port in the mandrel when the sleeve is in a first position, and the sleeve is axially-offset from the port in the mandrel when the sleeve is in a second position. A flow tube is coupled to the mandrel. The sleeve moves from the first position to the second position when fluid flows through the flow tube and through a channel disposed in the mandrel. A cutter block is movably coupled to the body and is responsive to fluid flow from the axial bore through the port in the mandrel.

Abstract: An example drilling turbine includes a turbine power section having a turbine shaft and a plurality of turbine stages axially arranged along the turbine shaft. A turbine bearing section is coupled to the turbine power section and has a drive shaft operatively coupled to the turbine shaft such that rotation of the turbine shaft rotates the drive shaft. The turbine bearing section includes a lower mandrel that houses a portion of the drive shaft rotatable with respect to the lower mandrel, one or more magnets disposed on an inner surface of the lower mandrel, a generator coil coupled to the drive shaft and aligned with the magnets, and one or more sensors coupled to the drive shaft and in electrical communication with the generator coil. The turbine shaft rotates the drive shaft, which rotates the generator coil with respect to the magnets, and thereby generates electrical power for the sensors.

Abstract: A method of configuring a depth of cut controller (DOCC) of a drill bit includes determining a first desired depth of cut for a first radial swath associated with a bit face of a drill bit. The first radial swath is associated with a first area of the bit face. The method further includes identifying a first plurality of cutting elements located on the bit face that each include at least a portion located within the first radial swath. The method additionally includes configuring a first depth of cut controller (DOCC) for placement on the bit face within the first radial swath. The first depth of cut controller is configured based on the first desired depth of cut for the first radial swath and each portion of the first plurality of cutting elements located within the first radial swath.

Abstract: A bottomhole assembly (BHA) coupled to a drill string includes one or more controllers, and a hole enlargement device that selectively enlarges the diameter of the wellbore formed by the drill bit. The hole enlargement device includes an actuation unit that may move extendable cutting elements of the hole enlargement device between a radially extended position and a radially retracted position. The actuation unit may be responsive to a signal that is transmitted from a downhole and/or a surface location. The hole enlargement device may also include one or more position sensors that transmit a position signal indicative of a radial position of the cutting elements. In an illustrative operating mode, one or more operating parameters of the hole enlargement device may be adjusted based on one or more measured parameters. This adjustment may be done in a closed-loop or automated fashion and/or by human personnel.

Abstract: 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.

Abstract: A well service rig system includes a well service rig, a catwalk, a racking system, and a tong system. The well service rig system provides techniques for tripping rods and/or tubulars with improved efficiency, such as reducing the need for operator intervention by providing process automation. The well service rig system is further adaptable for use with rods, tubulars, or both. The well servicing rig system also provides rod and/or tubular storage and delivery solutions via the integrated racking system. Furthermore, the present disclosure provides improved methods for tripping rods and/or tubulars.

Abstract: A tubular component for a drill stem that can be cabled includes a first end zone, a second end zone, a sheath, the sheath extends between the first end zone and the second end zone, and a liner fixed in a bore of the first end zone. The liner includes at least one take-up chamber for a cable disposed in the sheath.

Abstract: A method, apparatus and program product utilize infeasible regions projected onto sets of substantially parallel feasibility planes extending through a subsurface region to perform anti-collision and other types of hazard avoidance analysis. Hazards, e.g., existing well trajectories, that intersect the feasibility planes, as well as any uncertainties associated therewith, may be represented as infeasible regions in the feasibility planes, such that an analysis of the feasibility of a proposed well trajectory may be determined in a computationally efficient manner through a comparison of the locations, within one or more feasibility planes, of the proposed well trajectory and any infeasible regions defined in such feasibility planes.

Abstract: A method for deploying a tubular string into a wellbore includes: injecting fluid through a top drive and flow sub into a top of the tubular string and lowering the tubular string into the wellbore. The flow sub: connects the tubular string top to a quill of the top drive, is in a top injection mode, and has a closed port and an open bore. The method further includes halting injection of the fluid through the top drive and lowering of the tubular string. The method further includes, while injection and lowering are halted: disconnecting the flow sub from the tubular string top; adding one or more tubular joints to the tubular string and connecting the flow sub to a top of the added joints. The method further includes resuming injection of the fluid through the top drive and lowering of the tubular string.

Abstract: A bearing assembly for a drilling tool. A radial bearing assembly for use in a drilling tool may include a bushing having a generally cylindrical body with an inner surface. The radial bearing assembly may also include a sleeve configured to couple to a rotatable shaft of the drilling tool and configured to rotate within the bushing. The sleeve has (i) a plurality of spiral projections extending laterally in a direction away from a longitudinal axis of the radial bearing assembly and (ii) a plurality of flow paths, where a flow path of the plurality of flow paths is defined between a pair of adjacent spiral projections.

Abstract: A downhole assembly able to generate a vibrational output reliant upon a fluid feed drive to cause relative rotation extending magnetic arrays and thereby a relative longitudinal vibration causing reciprocation.

Abstract: An apparatus that includes one or more machined high-angle sockets and method for fabricating such sockets. The apparatus includes a body, one or more blades extending outwardly from the body, and one or more high-angle nozzles machined into a portion of the blade. The body includes a bit face at one end and a plenum formed therein communicably coupled to an opening formed at an opposing end. Each blade includes a leading section, a trailing section, a face section extending from one end of the leading section to an end of the trailing section, and an inner section extending from an opposing end of the leading section to an opposing end of the trailing section. Each nozzle includes a nozzle socket cavity and a second hole intersecting with the nozzle socket cavity and extending to the plenum, which collectively form a passage extending from the plenum to the bit face.

Abstract: A drill bit for drilling a borehole in an earthen formation may include a bit body having a bit axis and a direction of rotation about the bit axis; at least two blades extending azimuthally from the bit body; and a plurality of cutting elements disposed on the at least two blades; the plurality of cutting elements forming a cutting profile in a rotated profile view, each cutting element having a radial distance from the bit axis. At least one blade, at its formation facing surface, may include, between two radially adjacent cutting elements on the at least one blade, a raised depth of cut feature for each cutting element on the other of the at least two blades that are at radial distances from the bit axis intermediate the radial distances from the bit axis of the radially adjacent cutting elements on the at least one blade.

Abstract: A downhole cutting tool for drilling a borehole in an earthen formation may include a tool body having a tool axis and a direction of rotation about the tool axis; at least two blades attached to the tool body, the at least two blades having a leading face facing the direction of rotation of the tool body about the tool axis, a trailing face facing away from the direction of rotation of the tool body about the tool axis, and a formation facing surface extending between the leading face and the trailing face; and a plurality of cutting elements disposed on the at least two blades, each cutting element having a radial distance from the tool axis; wherein at least one blade, at its formation facing surface, comprises, between two radially adjacent cutting elements on the at least one blade, a raised depth of cut feature for each cutting element on the other of the at least two blades that are at radial distances from the tool axis intermediate the radial distances from the tool axis of the radially adjacent cutt

Abstract: A rotary drag bit for drilling subterranean formations includes a bit body having a face extending from a centerline to a gage. A plurality of blades may be disposed on the face, and may generally extend radially outwardly toward the gage. The bit may further include a plurality of discrete impregnated cutting posts, each of which may extend outwardly from an associated blade. Each discrete impregnated cutting post angles generally toward a front edge of the associated blade and generally toward the intended direction of rotation of the bit. The rotary drag bit may further include a plurality of matrix pockets disposed on the blades. The discrete impregnated cutting posts may be housed within corresponding matrix pockets.

Abstract: A dual drill string actuator includes a piston disposed in a housing. The housing is configured to sealingly couple at its longitudinal ends to an end of a nested dual drill string segment. An upper internal conduit is mounted in the housing proximate one longitudinal end thereof. A lower internal conduit is mounted in the housing proximate the other longitudinal end thereof. The piston is slidably, sealingly engaged between the upper and lower inner conduits and together define an internal fluid flow passage therethrough. The upper inner conduit, the piston and the lower inner conduit also define an external flow passage between respective exterior surfaces thereof and an interior of the housing such that application of fluid pressure to the external flow passage causes movement of the piston.

Abstract: An articulated reaming tool is provided in casing or liner drilling on or through the tubular wall with the articulation occurring from within the tubular. Outer limit travel stops are contemplated to optionally be used to retain the elements or blades to the tubular. In the case of liner drilling the drill string has an exterior protrusion to engage the movable components that ream and extend them to increase the clearance for the tubular as the tubular advances when more hole is made.

Abstract: A method for monitoring at least one subsea electric machine supplied by a system for electric power transmission. The system has a power supply, a controller and an AC power line connecting the at least one machine with the power supply. The method includes the steps of: receiving at the controller, high speed data from at least one subsea sensor arranged between the subsea side of the AC power line and the at least one subsea electric machine, wherein the high speed data includes measurements of an electrical parameter for the at least one machine; and comparing the one or more measurements to a predetermined value. A system for electric power transmission arranged for operating at least one subsea load or electric machine is also described.

Abstract: A method for designing a drilling plan for rock cavern excavation, which defines in advance for a round to be drilled in a tunnel face at least the locations of drill holes in a predetermined coordinate system, uses the drilling plan created by means of a computer-assisted design program. The method determines pull-out of a round on the basis of the locations of the hole ends and the topography of the rock remaining after a round blast, and designs or modifies the drilling plan for a subsequent round on the basis of the thus determined pull-out.

Abstract: A control system and method for operating a well completion system utilizing at least one computer programmed in one embodiment to automatically operate the movement of pipe from a pipe tub to the mast and into the well and/or for movement of the pipe out of the well and/or back into the pipe tub. In one embodiment, the computer is programmed and/or configured to coordinate operation of a top drive, and/or a pipe tong, and/or a pipe moving member for moving pipe into and out of a mast, and/or a pipe transfer system for moving pipe to the pipe moving member. In one embodiment, at least a portion of the at least one computer is mounted within a control van which may be positioned so that an operator within the control van can oversee operation of the well completion system.

Abstract: A first wireline tool embodiment includes a segmented tool body having a joint deployed between each adjacent pair of tool body sections. The joint may be configured to extend axially (causing a relative axial displacement of the adjacent tool body sections) when the wireline tool is subject to an axial load. The joint may include, for example, a compliant joint or a protractible joint. The joint may be further configured to cause a relative rotation between the adjacent tool body sections when the wireline tool is subject to axial load. A second wireline tool embodiment includes a plurality of standoff rings deployed about an outer surface of a rigid tool body. The standoff rings engage helical grooves in the outer surface of the tool body such that axial displacement of the tool body causes the standoff rings to rotate.

Abstract: A method, device, and system is described herein for pointing a rotary drill bit. A rotary bit pointing device is positioned between a proximal end of a control shaft and a universal joint. As the bottom hole assembly rotates, various portions of the rotary bit pointing device are enabled and subsequently disabled to apply a substantially constant force in a substantially constant direction to the control shaft. Such a force causes the distal end of the control shaft to point the rotary drill bit in a target direction.

Abstract: Expandable reamer tools include an outer body, a fluid passageway extending through the outer body, and at least one blade configured to slide relative to the outer body between a retracted position and an expanded position. In some embodiments, the tools may include a formation-engaging surface comprising a gage area. In other embodiments, the tools may include a radially recessed area extending from a back edge of the formation-engaging surface. Methods for removing such expandable reamer tools from a borehole are also disclosed.

Abstract: A method for coupling an earth pipe into the ground when utilizing an apparatus that has a drilling device including a casing part and a drilling unit inside thereof. The drilling unit includes a first drilling member for drilling a center hole and a second drilling member for reaming the center hole for the casing part. The casing part is arranged to be drawn into the hole by the first and/or second drilling member. After drilling a hole for the earth pipe and lifting up the first drilling member, a solidifying mass is led to the bottom of the hole to couple the earth pipe to the surrounding ground. The solidifying mass is brought in the casing part utilizing a flow-through assembly at a lower end of the casing part into a space between an outer surface of the casing part and the hole. Also an apparatus operating.

Abstract: A method for subsidizing wireless services in geo-fenced zones is provided in the illustrative embodiments. A geo-fenced zone is configured, the geo-fenced zone comprising a boundary defined by a set of fixed points in space. A subsidized pricing is configured for the wireless service when the wireless service is consumed by a mobile device within the geo-fenced zone, forming a subsidized wireless service. The mobile device is detected in the geo-fenced zone. The mobile device is provided the subsidized wireless service. A billing entry is applied to an account associated with the mobile device, wherein the billing entry charges the account a subsidized amount corresponding to a measured amount of subsidized wireless service used by the mobile device while the mobile device remains within the geo-fenced zone.

Abstract: Downhole tools are provided with a topographical pattern, and anti-balling material is provided over the topographical pattern. The topographical pattern may be defined by at least one of a plurality of recesses extending into a surface of a body of the tool and a plurality of protrusions protruding from the surface. Downhole tools include an insert disposed within a recess in a body, and the insert comprises an anti-balling material having a composition selected to reduce accumulation of formation cuttings on the tools when the tools are used to form or service a wellbore. Downhole tools include anti-balling material disposed over a porous mass provided over the surfaces of the tools. Methods of forming downhole tools include providing anti-balling material over features on and/or in a surface of a body of a tool. Methods of repairing downhole tools include removing an insert therefrom and disposing a replacement insert therein.

Abstract: A system, and computer program product for subsidizing wireless services in geo-fenced zones are provided in the illustrative embodiments. A geo-fenced zone is configured, the geo-fenced zone comprising a boundary defined by a set of fixed points in space. A subsidized pricing is configured for the wireless service when the wireless service is consumed by a mobile device within the geo-fenced zone, forming a subsidized wireless service. The mobile device is detected in the geo-fenced zone. The mobile device is provided the subsidized wireless service. A billing entry is applied to an account associated with the mobile device, wherein the billing entry charges the account a subsidized amount corresponding to a measured amount of subsidized wireless service used by the mobile device while the mobile device remains within the geo-fenced zone.

Abstract: A transportable rig apparatus provides single operator control for moving pipe into and out of a wellbore. A transportable control van houses the operator. A rig carrier is utilized to transport the mast. A pipe tong is mounted in the mast and is remotely operable from the control van. Rig blocks which move up and down in the mast are remotely operable from control van. A skid mounted pipe moving member moves pipe to the mast assembly and away from the mast assembly. The pipe moving member remotely is operable from the control van. A pipe tub stores pipe and a pipe tub transfer system is operable for moving pipe from the pipe tub to the pipe moving member and for moving pipe from the pipe moving member to the pipe tub.

Abstract: Earth-boring tools include a body and one or more replaceable cutting structures attached to the body at a face region of the body. Each replaceable cutting structure includes an attachment member and a cutting portion located to engage an earth formation. Methods of forming an earth-boring tool involve attaching one or more cutting elements to a replaceable cutting structure; positioning the replaceable cutting structure proximate a region of a body of an earth-boring tool that is susceptible to at least one of localized wear and localized impact damage; and attaching the replaceable cutting structure to the body. Methods of repairing an earth-boring tool involve bringing a replaceable cutting structure proximate at least one portion of a body of an earth-boring tool exhibiting at least one of localized wear and localized impact damage; and attaching the replaceable cutting structure to the earth-boring tool at the at least one portion.