Abstract: A portable frame assembly has a skid assembly for supporting a vertically oriented mast assembly. The mast assembly includes at least two column assemblies that may be extended or retracted vertically as desired. The mast assembly is translatable horizontally on the skid assembly. The skid assembly may be positioned adjacent a wellhead for the purpose of performing plug and abandon operations. The skid assembly may include a power swivel and other such hydraulic or mechanical tools for performing a variety of operations on a well including removing and plugging well casing strings, milling pipe strings, cement drilling, removing wellhead assemblies, or setting and pulling plugs from pipe strings.

Abstract: A downhole turbine assembly includes a stator housing having one or more stator blades positioned within the stator housing and extending radially inward therefrom. A rotor shaft having a first end and a second end is rotatably positioned within the stator housing and has a first portion exhibiting a first diameter and a second portion exhibiting a second diameter greater than the first diameter. One or more rotor blades are secured to the second portion for rotation with the rotor shaft, and a first bearing assembly is positioned at the first end and a second bearing assembly is positioned at the second end. At least one of the bearing housings provides a primary flow path and a secondary flow path, and one or more radial bearings and one or more thrust bearings are arranged in the secondary flow path.

Abstract: An electronic control system comprises a first tubular handling tool, a sensor, and a controller. The controller is configured to control actuation of the first tubular handling tool in response to an electronic signal received from the sensor that corresponds to an operational characteristic of the first tubular handling tool. The electronic control system functions as an electronic interlock system to prevent mishandling of a tubular. A method of controlling a tubular handling tool comprises measuring an operational characteristic of the tubular handling tool, communicating the operational characteristic to a controller in the form of an electronic signal, and using the controller to control actuation of the tubular handling tool in response to the measured operational characteristic.

Abstract: A derrick structure may include a plurality of drilling rotating/hoisting/circulation (RHC) traveling block/top drive like systems that can move between and are fully functional on multiple well centers. With such a configuration, one RHC can be disconnected from the drill lines and suspended in the drilling derrick allowing two hoisting systems with separate motors to function simultaneously on a single well center, thus doubling the lifting capability on that well center. For example, one traveling block may be suspended and its associated drill line and winch coupled to another traveling block on a different well center.

Abstract: An earth-boring tool comprises a body having a face at a leading end thereof, blades extending from the body and comprising primary blades and secondary blades, and cutting elements on the blades and arranged in groups each comprising neighboring cutting elements. Some of the groups are disposed only on the primary blades in a first spiral configuration. Others of the groups disposed only on the secondary blades in a second, opposing spiral configuration. Methods of forming an earth-boring tool, and methods of forming a borehole in a subterranean formation are also described.

Abstract: Coupling a top drive to tools. A drive unit includes a drive stem having torque gear profile, threaded load coupling, torque sleeve movable between first position and second position, a sleeve gear profile engaging the torque gear profile when in second position; or spindle unit and annular motor coupled to the spindle unit; or drive stem having first friction surfaces; transmission unit having second friction surfaces parallel to first friction surfaces; and transmission selector movable to an “on” or an “off” position. A method may include rotating a drive stem of drive unit, threading coupling with a tool stem of tool adapter; moving a torque sleeve of drive unit to engage a torque gear profile of the drive stem and a stem gear profile of the tool stem; or rotating a spindle unit relative to drive stem to contact a counter nut of spindle unit with the tool stem.

Abstract: A progressing cavity-type drilling motor having an electrical generator disposed within the rotor of the drilling motor. In some embodiments, the electrical generator produces electrical energy from a flow of drilling fluid through a bore in the rotor. In other embodiments, the electrical generator produces electrical energy by harnessing the kinetic energy of the rotor as the drilling motor is used to drill into a formation. The electrical energy generated by the generator can be stored or used to power sensors, actuators, control systems, and other downhole equipment.

Abstract: A well drilling system includes a flow control device regulating flow from a rig pump to a drill string, the flow control device being interconnected between the pump and a standpipe manifold, and another flow control device regulating flow through a line in communication with an annulus. Flow is simultaneously permitted through the flow control devices. A method of maintaining a desired bottom hole pressure includes dividing drilling fluid flow between a line in communication with a drill string interior and a line in communication with an annulus; the flow dividing step including permitting flow through a flow control device interconnected between a pump and a standpipe manifold.

Abstract: An orienting tool for use in wells can include a flow control device which controls flow between an interior and an exterior of a body of the tool to thereby transmit a signal indicative of an orientation of the body, the flow control device being outwardly extendable relative to the body. A method of orienting a structure in a well can include transmitting at least one signal from an orienting tool, the signal being indicative of an orientation of the orienting tool, and displacing a housing of the tool outward relative to a generally tubular body of the tool. A well system can include an orienting tool connected to a structure and positioned in a wellbore, the tool including a housing which is outwardly extendable relative to a generally tubular body, the tool being configured to transmit at least one signal indicative of an orientation of the structure.

Abstract: Methods of operating earth-boring tools may involve extending a selectively actuatable cutting element outward from a face of the earth-boring tool. A portion of an underlying earth formation may be crushed by a crushing cutting action utilizing the selectively actuatable cutting element in response to extension of the cutting element. The selectively actuatable cutting element may subsequently be retracted. Earth-boring tools may include a selectively actuatable cutting element mounted to a blade, the selectively actuatable cutting element configured to move between a retracted state in which the selectively actuatable cutting element does not engage with an underlying earth formation and an extended state in which the selectively actuatable cutting element engages with the underlying earth formation. The selectively actuatable cutting element may be configured to perform a gouging or crushing cutting action at least upon initial positioning into the extended state.

Abstract: An example drill bit includes a bit body defining at least one pocket, and a support arm attachable to the bit body at the at least one pocket and including a coupling that extends from the support arm. A roller cone defines a cavity for receiving the coupling to rotatably mount the roller cone on the coupling. A direct drive electrical power generator is positioned within the coupling and is operatively coupled to the roller cone such that rotation of the roller cone correspondingly rotates a portion of the direct drive electrical power generator to generate electrical power.

Abstract: An under-reaming tool comprises a body and a plurality of extendable cutters mounted on the body. The under-reaming tool is configured to be cycled between a first configuration in which the cutters are retracted and a second configuration in which the cutters are movable between retracted and extended positions. The under-reaming tool is configured to prevent extension of the cutters by an external fluid in the first and/or second configuration/s.

Abstract: The present invention relates to a robotically manipulatable wet-mateable subsea connection system suitable for use in harsh subsea environments. The robotically manipulatable wet-mateable subsea connection system of the present invention comprises a bulkhead receptacle unit, a flying lead plug unit, and a removable, reusable, robotically manipulatable connection tool.

Abstract: An inductive coupler includes a first transceiver electrically coupled to a first coil through a first tuning circuit. The inductive coupler may also include a second transceiver electrically coupled to a second coil through a second tuning circuit, where the second coil is positioned substantially concentric with the first coil.

Abstract: The present disclosure is directed to a drilling system. The drilling system includes drill string actuation mechanism having a first component and a second component configured to be rotated relative to the first component by a driving mechanism of the drill string actuation mechanism. The drilling system also includes a rotary transformer having a power input winding and a rotating power output winding. The power input winding is configured to be coupled to a power source and to the first component of the drill string actuation mechanism, and the rotating power output winding is configured to be coupled to the second component of the drill string actuation mechanism.

Abstract: A system, method and drill string component for directional drilling of a borehole in a formation is presented. The system includes a rotatable drill string, a rotatable drill bit comprising an intermediate space for receiving drilling fluid from the drill string and at least two nozzles for ejecting the drilling fluid. The system also includes a first rotor section, a flow diverter connected to a downhole end of the first rotor section, and a second rotor section being directly drivable by the drilling fluid and being rotatable with respect to the first rotor section in a second direction opposite to the first direction and at a second rotational speed (?3/2). In addition, the system includes a control unit for controlling the second rotational speed (?3/2) of the second rotor section with respect to the first rotor section.

Abstract: A method of increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, the method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using underbalanced coiled tubing drilling; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.

Abstract: A brake device for engaging an inner surface of a drill string within a borehole. The brake device has a driving member that defines a plurality of wedge surfaces, a brake retainer that receives at least a portion of the driving member, and a plurality of braking elements positioned in contact with at least a portion of the outer surface of the driving member. The brake retainer has a biasing member that is operatively coupled to the driving member. The biasing member of the brake retainer biases the driving member in a proximal direction relative to the longitudinal axis of the drill string to position the wedge surfaces in contact with corresponding braking elements, and the wedge surfaces drive the braking elements radially outwardly to engage the inner surface of the drill string. The brake device is not coupled to an inner tube assembly.

Abstract: An auger cleaning apparatus for the removal of debris and drilling substrate from the helical blades of an auger, the apparatus comprising two half-cylinder sections attaching by a hinge which encircle the outer perimeter of the auger, the two half cylinders forming a full cylinder, with at least one scraper directed to an inner cavity within the full cylinder, each scraper fitting within the voids between the threaded helical blade, scraping the debris and drilling substrate from the auger blade, each scraper extending between the spaces within the helical auger blade expelling the removed debris from the inner cavity through a respective evacuation port outside of the auger cleaning apparatus.

Abstract: A boring apparatus includes an upper member and a bit body configured to rotate relative to a pilot bit. A first end of the upper member is connected to a workstring. An inner cavity of the upper member includes a first radial cam surface. A first end of the bit body is connected to a second end of the upper member such that the bit body rotates with the upper member. A second end of the bit body includes a working face. The pilot bit includes a first end disposed within the inner cavity of the upper member, and includes a second radial cam surface configured to cooperate with the first radial cam surface to deliver a hammering force. The pilot bit extends through a central bore of the bit body, and includes an engaging surface on its second end configured to engage a formation surrounding the wellbore.

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: 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: 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: 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 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 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 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.