Abstract: A drill head for a drilling device for making drill holes in insufficiently stable foundation by displacement of soil material has a base plate, with which the drill pipe end is detachably connected and is closable, on which base plate at least one drill head plate, oriented substantially perpendicular thereto, is placeable. Insertable in the lateral flanks is at least one curved plate, which is provided with first holding means, which are held in second holding means, which are attached on the lateral flanks of the drill head plate. The curved plate is designed in a way and is insertable in the flanks of the drill head plate such that its surfaces are effective as screw faces during the drilling process. The efficiency of the drilling can thereby be improved.

Abstract: An earth boring bit has rotary cutters with embedded tungsten carbide inserts and milled steel teeth. The teeth and the grooves are first milled into the cutters, with the grooves extending between bases of the teeth, parallel to the crests of the teeth. Hard facing is applied to surfaces of the teeth and the grooves, and then the cutters are heat treated. Insert sockets are drilled into the teeth, centrally disposed in crests of the teeth. The tungsten carbide inserts are secured in the insert sockets, aligned for forming cutting profiles with respective ones of the milled teeth. The cutters are preferably frustoconically shaped and used for a rotary cone rock bit, and the tungsten carbide inserts configured as chisel-shaped inserts having crests which are aligned parallel to the crests of the milled steel teeth.

Abstract: Cutting elements for earth-boring tools include one or more recesses and/or one or more protrusions in a cutting face of a volume of superabrasive material. The superabrasive material may be disposed on a substrate. The cutting face may be non-planar. The recesses and/or protrusions may include one or more linear segments. The recesses and/or protrusions may comprise discrete features that are laterally isolated from one another. The recesses and/or protrusions may have a helical configuration. The volume of superabrasive material may comprise a plurality of thin layers, at least two of which may differ in at least one characteristic. Methods of forming cutting elements include the formation of such recesses and/or protrusions in and/or on a cutting face of a volume of superabrasive material. Earth-boring tools include such cutting elements, and methods of forming earth-boring tools include attaching such a cutting element to a tool body.

Abstract: Polycrystalline diamond cutters for rotary drill bits and methods of making the same are disclosed. A polycrystalline diamond compact includes a polycrystalline diamond body having a working surface, an interface surface, and a perimeter surface. The polycrystalline diamond compact also includes a substrate bonded to the polycrystalline diamond body along the interface surface. A non-diamond volume fraction of the polycrystalline diamond body is greater at the interface surface than at the working surface.

Abstract: A bit includes a bit body having at least one blade coupled to the bit body. The blade has a plurality of cutting elements at a nose region and a shoulder region of the blade. A plurality of fluid outlets are positioned on the blade such that at least 30% of the cutting elements have a fluid outlet within a distance that is two or three times a cutting element diameter away from a cutting face of the cutting element.

Abstract: A dual tower rig includes a hull supported by one or more legs and includes a cantilever assembly coupled to the hull. Dual towers are supported by a skidding system that is coupled to the cantilever assembly. The towers are configured to conduct independent operations and are movable relative to each other and to the hull by the skidding system and the cantilever assembly.

Abstract: An apparatus for locking a transmission line in a tubular includes a first clamp segment configured to surround at least a portion of the transmission line of the tubular, the transmission line having a longitudinal axis. The apparatus also includes a second clamp segment configured to surround at least a portion of the transmission line, the second clamp segment and the first clamp segment configured to apply radial forces in opposite radial directions when the first clamp segment is engaged with the second clamp segment, the opposite radial directions being perpendicular to the longitudinal axis, the radial forces operating together to maintain the transmission line in a fixed position relative to the tubular and maintain tension in the transmission line.

Abstract: This invention relates to a cable protecting device (5) for protecting cables (7) extending over a collar (2) on a pipeline (1), said collar extending around the circumference of the pipe and extending a known length outside said pipeline circumference, the collar having a first and second end surface, the cable protecting device (5) having a length in the direction of the pipeline being longer than the collar (2), and comprising a first recess along the inner surface for enclosing the cable (7) to be protected and a second recess in said inner surface for containing at least a part of the collar (2), the ends of said device at least partially covering the corresponding parts of the collar ends. The length of the second recess corresponds essentially to the length of the collar, each end of said second recess being provided with engaging means (4) adapted to engage with the corresponding end surface of the collar, thus fixing the protecting device (5) to the collar.

Abstract: A universal joint assembled to a drill string transfers torque and axial force between two components along a longitudinal axis where the shafts of the components are not completely aligned. The universal joint includes axially spaced members joined by transversely spaced links. As the joint rotates the links move to accommodate misalignment between the drill string components and the connected members.

Abstract: A tubular gripping assembly includes a power tong housing configured to actuate between an open position and a closed position, one or more valves coupled to the power tong housing, an inflatable bladder apparatus coupled to an inner surface of the power tong housing and configured to grip a tubular member when the power tong housing is in the closed position and the inflatable bladder apparatus is inflated, a latch mechanism configured to secure the power tong housing in the closed position and configured to allow the power tong housing to actuate to the open position, and a remote-controller device in wireless communication with the one or more valves. The remote-controller device is configured to control the power tong housing, the inflatable bladder apparatus, and the latch mechanism.

Abstract: A method of running tubulars includes attaching a load collar to a first tubular; landing the load collar on a load support member; connecting a second tubular to the first tubular; removing the load collar from the first tubular; and lowering the first tubular and the second tubular. In one embodiment, at least one of the first tubular and the second tubular is a screen.

Abstract: A tong assembly includes a power tong, a backup tong, and a carriage assembly operatively connecting the power tong and the backup tong. The carriage assembly includes a movable trolley assembly. The movable trolley assembly is axially located between the power tong and the backup tong. The movable trolley assembly is supported by the power tong. The movable trolley assembly is configured to axially move the power tong and backup tong relative to each other.

Abstract: A tubular guide assembly provides lateral support to a tubular extending through a BOP. The inner diameter of the BOP encasement is larger than the joint diameter. The assembly has a guide spool with a central bore extending therethrough along a longitudinal axis, wherein the diameter of the guide spool central bore is greater than the joint diameter of the tubular. At least two guide spool apertures extend radially inwardly through a wall of the guide spool to the central bore. A guide post for each guide spool aperture is movable through the respective guide spool aperture into the guide spool central bore to limit lateral displacement of a tubular extending therethrough. A method for providing lateral support to a tubular extending through a BOP during a snubbing operation uses their guide assembly.

Abstract: A borehole tool, having a cylindrical body, the cylindrical body having an upper shank, a lower shank, and a component tool disposed between the upper shank and the lower shank, wherein the tool is configured to have an outer surface airfoil configuration, whereby lift is created as fluid passes along the cylindrical body. The component tool can be a combination stabilizer tool, a reamer tool and a cutting removal tool, wherein the stabilizer tool is configured as a helical stabilizing blade and reamer blade, a flow path disposed between the helices of the stabilizing and reamer blade, the stabilizing and reamer blade further comprising a reamer cutting element disposed where an edge of the stabilizing and reamer blade meets the flow path.

Abstract: The invention relates to the field of stratum drilling, and in particular to a control method and a control device for drilling operations. The control method comprises: detecting whether an overflow occurs in a well; controlling the wellhead back pressure based on a preset bottom hole pressure when no overflow occurs in the well, in order to keep the bottom hole pressure stable; and performing a shut-in operation and controlling the wellhead back pressure based on the increase in fluid discharge returned from an annulus of the well when an overflow occurs in the well, so as to keep the bottom hole pressure stable and prevent the gas in the stratum from continuing to invade into the drilling fluid during the process that the overflow drilling fluid is discharged from the bottom of the well.

Abstract: A device (1) for ensuring continuous circulation in well drilling includes a tubular body (2), having an axial channel (2) with a lateral opening (3) which is closed by a removable plug (5). A tubular support (9) is placed in the axial conduit and supports a shut-off member (6) which is held in position by a retainer (14). The device (1) has an adjustment ring nut (50) which exerts a pressing action between the retainer (14) and the tubular support (9) to force the tubular support (9) in an axial limit-stop position against respective positioning and centering elements (11), to allow recovery of clearances during placement of the tubular support (9) and the valve (6) supported the tubular support inside the tubular body (2).

Abstract: A velocity string system includes a lock mandrel. A seal bore assembly attached to the lock mandrel runnable in a production string; and a velocity string sealable in the seal mandrel and separately runnable in the production string. A method for installing a velocity string system in a production string.

Abstract: A bailer bottom, bailer system, and method for performing bailer operations at a wellsite are disclosed. The wellsite is positioned about a wellbore penetrating a subterranean formation. The bailer bottom is deployable in the wellbore. The bailer bottom includes a plurality of downhole components and a select fire unit. The plurality of downhole components includes a cement unit which includes a cement chamber and a valve. The cement chamber has a port therethrough in selective communication with the wellbore via the valve. The select fire unit includes a downhole switch electrically coupled to the plurality of downhole components. The downhole switch has a polarity for each of the plurality of downhole components. The downhole switch is triggerable to selectively move between the multiple polarities to selectively pass a signal to one of the plurality of downhole components whereby the plurality of downhole components are selectively activated.

Abstract: An anchoring tool for positioning a downhole tool within a wellbore conduit is described herein. The anchor tool uses replaceable blades having protrusions that are configured to align with corresponding grooves in an anchor sub receptacle that is located at a known position along the wellbore conduit. The blades of the anchor tool are configured to move radially relative to the anchor tool body until the anchor tool is aligned with a compatible anchor sub. When the anchor tool and the compatible anchor sub are aligned, the protrusions of the anchor tool blade extend into the grooves of the anchor sub receptacle and a locking mechanism within the anchor tool inhibits further radial movement of the blades. A downhole tool connected to the anchor tool can therefore be positioned at a precise location relative to the known location of an anchor sub receptacle.

Abstract: A hybrid bit for use in a wellbore includes: a body having a shank for connection to a drilling motor or drill pipe and a plurality of legs attached to the shank; and a plurality of cutting structures. The cutting structures include a roller cone mounted to a first one of the legs and a fixed mill mounted to a second one of the legs and including a pad dressed with a cermet material.

Abstract: There are provided high power laser systems for performing decommissioning of structures in land based boreholes, and wells, offshore, and other remote and hazardous locations, and using those system to perform decommissioning operations. In particular embodiments the laser system is a Class I system and reduces emission of materials created during laser cutting operations. The laser systems can include lifting and removal equipment for removing laser sectioned material.

Abstract: A plug reception assembly having one longitudinal end and another longitudinal end includes a mandrel providing a flowpath configured to receive a plug to block flow therethrough; an elastic member forming a portion of a radially exterior surface of the assembly and having one longitudinal end and another longitudinal end; only a single set of slips arranged to maintain the assembly in anchored relation to a borehole, the slips disposed between the one longitudinal end of the assembly and the one longitudinal end of the elastic member, and the assembly being free of slips between the other longitudinal end of the assembly and the other longitudinal end of the elastic member; and at least one component of the assembly being disintegratable or dissolvable by a wave, a target fluid and/or a target temperature to facilitate removal of the assembly as a restriction in the borehole.

Abstract: Annular sealing structure associated with at least one annular support for sealing off against well casing said sealing structure including a first O-ring and at least two spaced annular sealing surfaces against which the O-ring seals in addition to sealing off against well casing.

Abstract: A well tube configured for use with a subsea well assembly which includes a Christmas tree arranged on top of a subterranean well. The well tube includes a bore, a lockable insert arranged within the bore, and a locking assembly. The locking assembly includes a locking dog which moves into and out of a locking position, an actuator which moves the locking dog, and a control channel which couples the actuator to an exterior of the well tube and controls the actuator to move the locking dog to removably lock the lockable insert within the bore.

Abstract: An apparatus for controlling hydraulically actuatable components of a blowout preventer stack assembly and a system for same. The apparatus comprises a blowout preventer stack including hydraulically actuatable components and a lower marine riser package coupled to the blowout preventer stack and including additional hydraulic components. The lower marine riser package includes a solenoid valve configured to control at least some of the components. The solenoid valve receives hydraulic fluid from a dedicated accumulator or accumulator bank configured to supply hydraulic fluid exclusively for use with the solenoid valve. A closed-loop hydraulic circuit is formed between the accumulator or accumulator bank and the solenoid valve.

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

Abstract: A degradable downhole isolation tool for use in hydrocarbon well completion. The tool sets and isolates zones for fracking, and then degrades without leaving residual parts and without milling or introducing a new degrading fluid. The plug's mandrel and other parts are a solid polymer which hydrolyzes in aqueous downhole fluid to produce an acid which degrades degradable metal slips and other metal parts. The plug's seal may be degradable metal pedals or split rings. The plug is delivered to the well site as an interchangeable parts kit for adaption to the well's requirements.

Abstract: A downhole tool includes a housing including a connection for coupling with a conveyance that extends from a terranean surface into a wellbore; a first tubular member coupled with the housing, the first tubular member including a first compound cylinder; and a second tubular member coupled with the housing and concentrically positioned radially adjacent the first tubular member, the second tubular member including a second compound cylinder, the first and second tubular members defining a pressure chamber between an inner surface of the first tubular member and an outer surface of the second tubular member.

Abstract: A method of closing a fluid flow path in a wellbore is disclosed that in one non-limiting embodiment includes: supplying a flexible structure having a selected shape sufficient to seat on an opening of the fluid flow path, the flexible structure including pores of selected dimensions; determining seating of the flexible structure on the opening of the fluid flow path from a sensor measurement; and supplying a slurry containing a sealant to the flexible structure seated on the opening of the fluid flow path to plug the pores with the sealant to close the fluid flow path.

Abstract: Systems, compositions, and methods for reducing the production of water in subterranean formations having fractures or voids therein are provided. In one embodiment, the methods comprise: introducing a particulate material into a portion of a subterranean formation comprising one or more fractures or voids; and introducing a treatment fluid comprising a relative permeability modifier into the portion of the subterranean formation such that the permeability of the particulate material in the portion of the subterranean formation to water is reduced.

Abstract: A technique facilitates selection of optimum flow control valve settings to improve a desired objective function in a multizone well having zonal isolation. A network of flow control valves is provided in a completion network disposed along isolated well zones of at least one lateral bore of the multizone well. Data is acquired from downhole in the multizone well and processed on processor system modules which may be used in selected combinations. Examples of such modules comprise completion network modules, deconvolution modules, optimization modules, and/or inflow-outflow modules. The modules are designed to process the collected data in a manner which facilitates adjustment of the flow control valve settings in the network of flow control valves to improve the desired objective function.

Abstract: A device, such as a valve, includes a hard seat having an axial bore extending along a central axis. A flapper pivotally connected with the hard seat at a hinge axis and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore, the flapper having a flapper sealing surface that slopes inward toward the central axis along a full circumference of the flapper sealing surface and the hard seat having a hard sealing surface that slopes inward toward the central axis conforming to the flapper sealing surface and on which the flapper sealing surface bears when in the closed position.

Abstract: A downhole tool and method, of which the downhole tool includes a first sub defining a port extending radially therethrough, a second sub spaced apart from the first sub, and a housing connected with the first and second subs. A valve element is disposed at least partially within the housing, and is movable from a closed position to an open position. In the closed position, the valve element blocks fluid communication between a bore and an opening in the housing. When the valve element is in the open position, fluid communication between the bore and the opening is permitted. An actuation chamber is defined between the first sub, the housing, and the valve element, and is in fluid communication with the bore via a flow path that includes the port. A flow restrictor in the flow path is configured to slow fluid flow from the bore to the actuation chamber.

Abstract: A tubing drain for service with oil wells, water wells, gas wells and/or thermal wells has a configuration of structural features which allow the drain to be opened and closed without the need to pull the drain to the surface to be serviced. The drain utilizes an inner mandrel having two circumferentially aligned cylindrical apertures which may be selectively aligned with a drain port in an outer shell member as the inner mandrel is rotated within the shell. A first cylindrical aperture contains a ball which, when in alignment with the drain port, is urged against a seat in the drain port by hydraulic pressure. However, when the inner mandrel is rotated the ball is dislodged from the seat and forced back into the first cylindrical aperture. Further rotation of the inner mandrel aligns the second cylindrical aperture with the drain port, allowing the tubing to drain.

Abstract: A tubular assembly includes a turbular member having at least one opening, and a sleeve slidingly mounted relative to the tubular member. The sleeve is shiftable between an open configuration in which the at least one opening is exposed and a closed configuration in which the at least one opening is covered by the sleeve. A degradable locking member is mounted relative to one of the turbular and the sleeve. The degradable locking member selectively retains the sleeve in the open configuration. The degradable locking member is configured to degrade when exposed to a downhole fluid allowing the sleeve to be shifted to the closed configuration.

Abstract: A downhole tool, such as a sliding sleeve, is operable with pressure applied against one of a plurality of plugs deployed in the tool. A sleeve can engage the deployed plugs and can move with the engagement. The sleeve extends in an absence of external support and releases the engaged plug. An indexing mechanism operable between the sleeve and an insert in the tool moves with the sleeve in response to the engagement with the deployed plugs and counts those engagements. In response to a predetermined count, the indexing mechanism forms the external support of the one deployed plug engaged in the sleeve and moves the insert with the pressure applied against the one deployed plug, which is engaged in the sleeve and supported by the indexing mechanism. For example, the insert can move open in the tool relative to a flow port communicating outside the tool.

Abstract: An insulating packer fluid including an oleaginous fluid and a styrenic thermoplastic block copolymer and methods of preparing the packer fluid are provided. Also provided are methods of using the insulating packer fluid that include pumping an insulating packer fluid into an annulus formed between two concentric strings of pipe extending into a wellbore.

Abstract: A hydrocarbon heating system for a hydrocarbon production and/or transportation system comprising at least one electrical conductor and an alternating current (AC) power source connected to the at least one electrical conductor. The alternating current power source generates heat in the at least one electrical conductor by providing alternating current power to the at least one electrical conductor.

Abstract: A platform apparatus positionable close to a surface element to allow an operator to access production tubing being withdrawn from the surface element. The platform apparatus can be positioned in close proximity to a surface element of a well to permit an operator access to production tubing and cable secured to the production tubing. The cable can be separated from the production tubing. The production tubing can be scanned with an electronic scanning device after the cable has been separated from the production tubing as the production tubing is being removed from the well. The platform apparatus can be positioned in close proximity to a surface element of a well being serviced by a pole unit to permit an operator access to production tubing. The production tubing can be scanned with an electronic scanning device as the production tubing is being removed from the well.

Abstract: The present invention relates to a completion method for completing a uniform inner bore downhole completion system in a reservoir in a formation, comprising the steps of drilling a hole in the formation, inserting a surface casing having an inner surface casing diameter, cementing an outer face of the surface casing to the hole, inserting a drilling head in the surface casing, drilling a main bore extending from the surface casing, the main bore having a first part and a second part, the second part comprising an end of the main bore, and the main bore having an inner main bore diameter which is substantially the same as the inner surface casing diameter of the surface casing, retracting the drilling head from the main bore and the surface casing, inserting a lower production casing in the second part of the main bore, the lower production casing having annular barriers and an inner diameter, setting at least one of the annular barriers of the lower production casing, inserting the drilling head into the fir

Abstract: Disclosed are systems, methods, and apparatuses to detect one or more downhole laterals in a wellbore using electromagnetic sensors. Certain embodiments include a subsurface unit including a ruggedized encapsulation resistant to heat, pressure, and variations in pH. The systems and apparatuses are communicable with surface controls.

Abstract: A method for estimating a permeability of an earth formation includes: receiving a discrete fracture network (DFN) of the earth formation; representing the DFN as one or more volume sections, each volume section having a plurality of boundaries; identifying fractures that are connected to each other and lead from a first boundary in the plurality of boundaries to a second boundary in the plurality of boundaries to provide one or more flow paths for each volume section; applying Oda's method to the connected fractures making up the one or more flow paths to estimate the permeability of the earth formation along the one or more flow paths for each volume section to provide a permeability value for each volume section; and performing an action related to the earth formation using the permeability value for each volume section and an apparatus related to the action.

Abstract: A method to drill a borehole or wellbore through an earthen formation using a drill bit on a drillstring, comprising the steps of: selecting a frequency-domain dynamic model of a drilling assembly that describes the dynamic response of the drilling assembly to excitation at an excitation frequency for operating at a set of selected drilling parameters that include at least rotary speed and weight on bit; calculating a composite vibration index by combining calculated vibration indices for each excitation frequency with the spectral weighting factors for each of the drilling parameter partitions; displaying said composite vibration index for each of the drilling parameter partitions; selecting preferred drilling parameters based on the displayed results, and using the preferred drilling parameters to drill a borehole with the modeled drilling assembly.

Abstract: An apparatus has an elongate body defining an interior chamber and a gas passage in communication with the interior chamber. The elongate body further includes a base defining a liquid opening and a cap defining an outlet opening. The liquid opening is adapted to receive a liquid disposed in a wellbore. The gas passage is adapted to receive a gas. An outlet of the gas passage is disposed a first distance from the base and an inner conduit is disposed in the interior chamber. The inner conduit includes a first open end in communication with the liquid opening and a second open end in communication with the interior chamber. The second open end is disposed a second distance from the base.

Abstract: A method of injecting fluid into a formation, comprises exerting a mechanical force on a wall of a bore extending through a formation to modify the permeability of the formation; and injecting fluid into the modified formation. The mechanical force is exerted through inflation of at least one pressure deformable member mounted on a base member with a retaining ring.

Abstract: A liner hanger seals with casing string 8 having mill scale and supports a liner 98 within a well. The liner hanger includes a tubular anchor 48 and a tubular expander 40. The tubular anchor 48 may be positioned in the casing string 8 using an inner mandrel 10. An actuator assembly 6 forcibly moves the tubular expander 40 into the tubular anchor 48, expanding the tubular anchor 48 to grippingly engage the expanded tubular anchor 48 against the casing string 8 and to form a circumferential seal between metal sealing elements 52 on the tubular anchor 48 and the interior wall of the casing string 8. The metal sealing element 52 is oversized to provide rigidity, heat shrunk onto the tubular anchor 48, and abrasively dressed to remove excess material prior to installation of the liner hanger.

Abstract: A perforating apparatus for a gun string is presented. The apparatus experiences an axial load and potentially a radial load during use. A central charge-carrier supports shaped-charges and substantially bears the axial load on the apparatus during use. The charge-carrier is positioned within an exterior sleeve and the plurality of shaped-charges, upon detonation, perforate the exterior sleeve. The exterior sleeve does not bear a substantial portion of the axial load on the apparatus and can therefore be thinner and cheaper than in prior art assemblies. An annular space can be defined between the charge-carrier and exterior sleeve. The exterior tubular can bear the radial load due to differential pressure in one embodiment. Alternately, the apparatus includes radial support members extending between the charge-carrier and sleeve for transmitting radial load to the charge-carrier. Alternately, the sleeve and charge-carrier abut one another along a substantial portion of the length of the charge-carrier.

Abstract: A wellbore perforation gun includes a gun housing, a plurality of charges, a first reactive material, and a second reactive material that is reactive with the first reactive material to generate an endothermic chemical reaction to drop the potential energy (in the form of temperature or pressure) of the gun housing. The perforation gun may further include a controller and a release capsule, with the first reactive material being disposed within the release capsule and the second reactive material being disposed within a chamber of the gun housing at a first time. The controller may be communicatively coupled to the release capsule and operable to generate a signal to the release capsule at a second time that is later than the first time. The release capsule may be operable to release the first reactive material into the chamber response to receiving the signal.

Abstract: A perforating gun assembly for use in a wellbore includes a carrier body and a charge holder disposed within the carrier body. One or more shaped charges are supported by the carrier body and are operably coupled to a detonator for igniting a highly explosive material within the each of the shaped charges. At least one solid propellant tablet is also disposed within the carrier body and is operably coupled to the detonator to ignite and burn immediately after detonation of the shaped charges. The solid propellant tablet burns or is consumed in such a manner to effectively mitigate or control the dynamic underbalance created by the free volume within the carrier body. Burning of the solid propellant tablet may increase the pressure within the carrier body to a level lower than a hydrostatic pressure around the carrier body in the wellbore such that a dynamic underbalance is maintained.

Abstract: An assembly for circulating tool fluid of a downhole tool includes a tool fluid source line extending into a subterranean well from a wellhead spool assembly to the downhole tool. A tool fluid return line extends out of the subterranean well from the downhole tool to the wellhead spool assembly. A tool fluid reservoir is located at a surface outside of the subterranean well. The tool fluid source line is in one way fluid communication with the tool fluid reservoir and the tool fluid is free of fluid communication with wellbore fluids.