Abstract: A modular rotary claw drill bit having a head is mountable at a body, the head mounting a plurality of front and gauge cutting picks. A cutting tip of each front pick is located at a different radial position at the head to optimise the flushing of cut material and to minimise pick wear during use.

Abstract: A downhole drill bit, of the type used to bore into the earth when searching for or extracting subterranean resources, may comprise a working face opposite an attachment end and an opening passing from the attachment end through to the working face. A protrusion on one end of a bottom hole assembly may extend through the opening and be exposed at the working face when the drill bit is attached to the end of the bottom hole assembly. In various embodiments the exposed portion of the protrusion may house conduits or nozzles for handling fluids; sensors, transmitters or wires for handling electrical signals; or mechanical hammers, motors or cutters for degrading an earthen formation. In this way, the protrusion may bring such elements from the bottom hole assembly to the working face of the drill bit.

Abstract: A drilling rig may include a right substructure, left substructure, and a drill floor. The drill floor may be pivotably coupled to lower boxes of the left and right substructure by struts. The substructures may include hydraulic cylinders positioned to raise the drill floor and a mast coupled to the drill floor into a raised position.

Abstract: A flotation system includes one or more floatation modules, each having a first section and a second section, each having an internal core made of a buoyant material. The first section includes two end faces and a projection extending from one of the end faces. The projection has a contoured profile. The second section includes two end faces and a reciprocal recess in one of the end faces. The end faces of the first section engage the end faces of the second section such that the projection engages the reciprocal recess in a mating engagement. The outer surface of the flotation module include one or more grooves providing a pathway for the flow of circulation fluid. The floatation system may be attached to a tubular string during inner string cementing operations to reduce the load applied to the platform.

Abstract: An integrated casing drive system combines a top drive having a rotary drive portion, a pipe handler having a casing gripper wherein the pipe handler is rotationally mounted to the top drive, and a selectively actuable casing drive lock for locking the rotary drive portion to the pipe handler.

Abstract: A power tong positioner has one or more eddy current probes mounted in association with a power tong/backup unit. An electric current runs through the probe, and with the probe positioned close to a tubular connection, movement of the probe along the length of the connection, with the electric field encompassing surface features on the tubular, will cause a change in the electrical impedance (conductivity) which enable identification of the connection seam or other defined attributes (the “target” attributes). The power tong/backup unit can be positioned accordingly. A portfolio of profiles of non-connection seam surface features of different tubular connections may be generated, stored in a database, and accessed by the system, which enables identifying the connection seam/face with greater accuracy. Other attributes of the invention include storing profile information on RFID tags, and storing and accessing tubular information from a cloud server or other form of remote database.

Abstract: A coiled tubing rig includes a skid, a mast, and a drill floor. The mast may be pivotably coupled to the skid and may be moved between a horizontal position and a vertical position by a hydraulic cylinder. The drill floor may be pivotably coupled to the mast. The drill floor may be moved from a retracted to a deployed position by a hydraulic cylinder. The skid may include a BOP cradle and BOP controls. The coiled tubing rig may include a jib which may telescopically or pivotably extend from the mast. The coiled tubing rig may include a coiled tubing injector which is slidably positionable between a retracted and a deployed position.

Abstract: A system for mud solid control includes a translational elliptical multilayer ultra-wide screen shaker, a degasser, a solid-liquid separator, a large capacity centrifugal machine and a collector for solid shales. The solid-liquid separator includes a base which is provided with a feed tank and vibrating supports. A vibrating tank is fixed to the vibrating supports, and screen drums, vibration motors and an anti-vibration driving motor are assembled on the vibrating tank. The anti-vibration driving motor is connected to the screen drums. Each of the screen drums includes an inner drum, an intermediate drum and an outer drum. The system and a corresponding process thereof can greatly simply and improve the process for mud solid control and relevant devices, improve usage effect, reduce cost, save electrical power, reduce occupied area and simply maintenance and management of devices involved.

Abstract: A method of operating a gas extraction system includes receiving a drilling fluid sample at a flow meter via a flow meter inlet conduit and discharging the drilling fluid sample into a flow meter outlet conduit. A first inline mud valve positioned in the flow meter inlet conduit and a second inline mud valve positioned in the flow meter outlet conduit are each closed to transition the gas extraction system to a bypass flushing configuration. A bypass flow meter valve positioned in a flow meter bypass conduit is opened to divert the drilling fluid sample around the flow meter. The flow meter is then flushed with flushing fluid by opening first and second flow meter flushing valves and starting a pump to circulate the flushing fluid through the flow meter.

Abstract: A drill string (2) for a floating drill rig, the drill string (2) comprising: a bore (4) running the length of the drill string (2) and configured to receive a drilling fluid; and a controllable dynamic flow restriction (14) in the bore, wherein the controllable dynamic flow restriction (14) is operable to restrict flow of the drilling fluid through the bore (4) and thereby generate excess pressure in the drill string when the drill string (2) moves down, and to allow additional drilling fluid to be pushed through the bore (4) and out of the fluid connection under the excess pressure generated when the drill string (2) moves upward.

Abstract: A packer assembly includes an elongate body, an upper shoulder and a lower shoulder each disposed about the elongate body, and an upper sealing element and a lower sealing element each disposed about the elongate body and positioned axially between the upper and lower shoulders. A spacer interposes the upper and lower sealing elements and has an annular body that provides an upper end, a lower end, and a recessed portion extending between the upper and lower ends. A diameter of the annular body at the upper and lower ends is greater than the diameter at the recessed portion.

Abstract: The present invention provides a tool (1) for removing metal debris from a well bore, comprising a magnet element (2), rotation generating means (5), a debris removal unit (3) and a debris container (6), wherein the magnet element comprises a cylinder-shaped housing (10) having a first end (7) and a second end (8); the debris removal unit (3) comprises a first helix-shaped longitudinal guide element (4) arranged around the cylinder-shaped housing; the rotation generating means (5) are operably connected to the cylinder-shaped housing or the first helix-shaped longitudinal guide element; the debris container (6) comprises a first opening (9) arranged at the second end (8) of the cylinder-shaped housing, wherein the cylinder-shaped housing (10), or the first helix-shaped longitudinal guide element (4), is rotatable around its centreline (C), and configured such that metal debris accumulating on the cylinder-shaped housing during use is guided by the first helix-shaped longitudinal guide element towards the firs

Abstract: Directional control valves with blind shear rings are provided. In one embodiment, a valve includes a piston within an inner chamber of a hollow body having inlet and outlet ports in fluid communication with the inner chamber. The valve includes a shear seal ring positioned in the piston and seated against an interior surface within the hollow body. The shear seal ring includes an interior cavity for allowing fluid communication between the inlet port and the outlet port via the interior cavity depending on the position of the piston. Further, the valve includes a blind ring positioned in the piston. At least a portion of the blind ring is exposed to fluid via the interior cavity of the shear seal ring, and the blind ring prevents flow of fluid from the interior cavity of the shear seal ring through the blind ring. Additional systems, devices, and methods are also disclosed.

Abstract: A method can include increasing a pressure differential from an interior to an exterior of a packer, thereby deactivating a lock that prevents setting of the packer, and applying a compressive load to a tubular string, thereby setting the packer. A packer can include an annular seal that extends radially outward in response to a compressive load applied to opposite ends of the packer, and a lock that prevents relative longitudinal displacement between sections of the packer, the lock including a radially displaceable piston. In another packer, an inner mandrel can have circumferentially spaced apart engagement structures that are engageable with other circumferentially spaced apart engagement structures, displacement of one packer section relative to another packer section in a longitudinal direction being prevented when the engagement structures are engaged, and such displacement being permitted when the engagement structures are rotationally misaligned.

Abstract: A downhole tool includes a mandrel and a deformable seal positioned around the mandrel to hold overpressure. An extrusion limiter is positioned around the mandrel, and adjacent to the deformable seal. The extrusion limiter includes a body, and grooves formed into the body that separate fins. The grooves have at least one portion formed at an acute angle relative to a circumferential line centered on the central axis of the extrusion limiter body. After the bending of the fins that occurs in use of the extrusion limiter, the gaps left by the grooves between the fins may be smaller than gaps left by straight grooves that are perpendicular to circumferential lines centered on the central axis of the body. The smaller gaps reduce extrusion of the deformable seal.

Abstract: A tapered mandrel is advanced into a spirally cut sleeve having a corresponding taper to the mandrel. The outer surface of the sleeve conforms to the surrounding borehole and features an exterior recess in which a sealing element is mounted. The sleeve diameter expands as the tapered mandrel is axially advanced. Axial cuts in the spiral sleeve further reduce the force needed for setting. A leading nose is provided for the uphole end of the sealing element to allow high treatment flow rate while the sealing element is protected from the erosive effects of high velocities.

Abstract: A method of actuating a selected electrically powered device such as a solenoid operated valve (SOV) among a plurality of electrically powered devices coupled between a first conductor and second conductor includes applying a high voltage differential between the first conductor and the second conductor, the high voltage being at least as high as the breakover voltage of a switching thyristor coupled to the selected electrically powered devices. The method also includes applying a low voltage differential between the first conductor and the second conductor after applying the high voltage, the low voltage being lower than the breakover voltage of any switching thyristor coupled to the plurality of electrically powered devices.

Abstract: A device in accordance to an embodiment includes a tubular housing having an inside diameter defining an axial bore, a top surface and an outer surface, a groove formed along the outer surface below the top surface, a flapper pivotally connected with the housing and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore and a torsion spring having a spring diameter and disposed in the groove and in connection with the flapper to bias the flapper to one of the open and the closed position. The torsion spring may be nested in a C-shaped groove.

Abstract: A device, such as a valve, having a soft seat disposed in a groove formed in and circumferentially along a hard seating surface of a hard seat and one or more retaining elements disposed in the groove in contact with the soft seat and the hard seat.

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: Backflow prevention assemblies and methods for downhole systems having outer strings and inner strings include a housing defining a cavity and being part of the outer string, a flow tube disposed between the inner string and the outer string movable axially within the outer string, and a backflow prevention structure having a flapper and a seal seat, the flapper biased toward a closed position and maintained in an open position by the flow tube. The flapper is housed within the cavity when in the open position and the flapper and seal seat form a fluid seal to prevent fluid flow into or through the flow tube when in the closed position. When the flow tube is moved from a first position that maintains the flapper in the open position to a second position, the backflow prevention structure operates to close the flapper and seal the backflow prevention structure.

Abstract: A downhole tool in accordance to aspects of the disclosure includes a housing forming a bore to convey a wellbore fluid, an actuating piston moveably disposed in a cylinder located in the housing adjacent to the bore and a barrier fluid isolating the actuating piston from the bore. The downhole tool may include a compensator piston in communication with the barrier fluid and the bore that is moveable to balance the pressure between the barrier fluid and the bore.

Abstract: A diverter valve housing is secured to an upper end of a pump. A shuttle in the diverter valve housing moves between an upper closed position and a lower open position. A floating ring has an exterior band that abuts an upper end of the shuttle to move the shuttle downward. The floating ring moves upward when the pump operates. A bushing abuts an upward facing shoulder in the floating ring and is adhered within the bushing by a layer of adhesive. The shuttle has upper and lower seals separated by upper and lower spacer rings. A stop ring between the spacer rings limits downward movement of the upper spacer ring and also limits upward movement of the lower spacer ring.

Abstract: Various systems, methods, and devices are disclosed for handling contaminants in a wellbore or riser. A washpipe debris trap (WPDT) traps contaminants traveling up a wellbore from a downhole location, and the WPDT may serve as an indicator for a breached screen in a downhole location. A marine riser reversing tool (MRRT) may reverse the flow of fluid between a workstring conduit and an annulus between the workstring and the wellbore such that fluid rises to the wellhead with greater velocity. A bi-directional chamber trap (BDCT) may be utilized in a wellbore operation to remove contaminants from a fluid.

Abstract: A system is provided that allows relatively low temperature water to be withdrawn from a pipeline, heated and then returned to the pipeline. At least one embodiment includes a device for adjusting the rate of flow through a primary pipe so that desired temperatures are maintained during the heating process.

Abstract: A system for emptying a gravity separated crude oil including a flexible bag storing the crude oil arranged within a protection structure, the protection structure including a bottom dement forming the lower section of the protection structure, the flexible bag being connected to a flange that is connected to the protection structure, and includes at least one fluid conduit providing fluid communication between the flexible bag and outside the protection structure A first outlet pipe is arranged inside the flexible bag near the bottom dement and is connected to and in fluid communication with the at least one fluid conduit A perforated tube surrounding the outlet pipe provides an annulus fluid passage, water is supplied to the structure volume, and the crude oil is emptied through the at least one fluid conduit, through the perforations in the perforated tube, through the annulus fluid passage to the first outlet pipe.

Abstract: A method may include receiving, via a processor, data related to properties associated with injecting a slurry into a subsurface region of the Earth from one or more sensors disposed within the subsurface region. The method may then determine whether the data is within a threshold of simulated data determined based on a simulation of injecting the slurry into the subsurface region over a simulated period of time. The simulation is generated using a geomechanical model having mechanical properties associated with the subsurface region. The method may then generate an updated geomechanical model based on the data and automatically send commands to adjust operations of components that control an injection of the slurry into the subsurface region based on the updated geomechanical model.

Abstract: Method and system for optimizing production from an oil and gas reservoir includes selecting a geocellular grid representing at least one property of the reservoir, defining a data range for the property that reflects uncertainty regarding which values may be used for the property, defining a first reservoir simulation model, simulating production from the reservoir with the model using the at least one property, comparing the output of the simulated production from the reservoir with a predetermined criteria based on historical data, and modifying the property to a different value within the data range for the property if the predetermined historical criteria is not met. These steps may be repeated for at least two values for the property within the data range. The above may be repeated for a second reservoir model and the outputs of the simulated production for the models may then be ranked according to predefined criteria.

Abstract: An underwater hydrocarbon processing facility has at least one fluid processing clusters provided with modules having, each, one fluid processing device and a plurality of first connection members configured to define the inlet and the outlet of the process fluids; and an interconnection unit having a plurality of second connection members defining inlet and outlet for the process fluids and configured to be operatively coupled to corresponding first connection members configured to operatively interconnect the modules.

Abstract: A single-trip method and system for perforating casing allows displacement of a heavier completion fluid from the perforation zone by a lighter formation-compatible treatment fluid without the need for an extended rat hole or repositioning the working string. The perforating system includes bridge subs located above and below a perforating gun. The bridge subs bypass treatment fluid around the gun through one or more conduits located along the exterior of the gun into a discharge flow port located immediately below the lower bridge sub. The system may be hydrodynamically designed to maintain efficient fluid displacement characteristics of the discharge flow port. The external conduits are positioned to not interfere with perforation operations and may include parallel conjoined tubes. The perforating system may be lowered to a perforation position in the wellbore, and treatment fluid pumped through the discharge flow port to displace completion fluid prior to perforation operations.

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: A gas compressor system is provided to operate at a well site and to inject a compressible fluid into a wellbore in support of a gas-lift operation. Methods and systems are provided that allow for the automated individual control of discharge temperatures from coolers for gas injection, in real time, wherein the temperature control points of the first and/or second stage cooler discharges are automatically controlled by a process controller in order to push heat produced by adiabatic compression to a third or final compression stage. In this way, discharge temperatures at the final stage are elevated to maintain injection gaseous mixtures in vapor phase.

Abstract: Systems and methods for operating a linear motor (e.g., for an ESP), where the motor's mover moves in a reciprocating motion within a bore of the stator. Hard stops are located at the ends of the bore. The motor has a first set of sensors in the stator positioned proximate to the bore. When the mover moves in the bore, the sensors produce corresponding output signals, except when the mover is in a position near, but not in contact with a hard stop. While the sensors produce output signals, the motor is driven in a first direction toward the hard stop. When the sensors stop producing the output signals, the mover has reached the first position, and the motor is controlled to reverse the direction of the mover.

Abstract: Optimized enhanced oil recovery can include tuning of injection rates during a recovery operation. The injection rate of injection fluid pumped into a formation can be controlled to alternate between monotonically increasing and monotonically decreasing during the enhanced recovery operation. Injection rates can be monotonically increased to a maximum level (e.g., as defined by physical constraints of the system) and then monotonically decreased to a lower level, allowing the injection rates to be monotonically increased again. While injection rates are monotonically increasing, viscous fingering between the injection fluid and hydrocarbons can be minimized while the hydrocarbons in the formation are displaced. While injection rates are monotonically decreasing, creation of new viscous fingers can be minimized while the injection rates are decreased to levels suitable for the monotonic increasing phase of a subsequent monotonic cycle.

Abstract: The invention provides an isolated bacterial strain selected from the group of bacterial strains deposited under accession number ECACC 15010609; ECACC 15010601; ECACC 15010602; ECACC 15010603; ECACC 15010604; ECACC 15010605; ECACC 15010606; ECACC 15010607; ECACC 15010608; and a bacterial strain having all the identifying characteristics of one or more of the strains. The use of said bacterial strains in a method of treating an oil reservoir, a method of bioremediation and a method for the production of a biosurfactant-like substance is also provided. The invention still further provides a biosurfactant-like substance so obtained and the use thereof in method of enhanced oil recovery (EOR) and a method of environmental remediation.

Abstract: Oil and gas recovery includes selecting a previously used oil or gas containing layer in which cumulative perforation was utilized, closing micro cracks over a thickness of the oil or gas containing layer, carrying out slotting of the oil or gas containing layer to form slots, producing micro cracks over the thickness of the oil or gas containing layer, carrying out hydraulic fracturing of the oil or gas containing layer, and withdrawing oil or gas from the oil or gas containing layer with maintaining of a pressure in the well.

Abstract: A fiber delivery system capable of providing cut fiber segments for use in treating an oil and/or gas well. The fiber delivery system can utilize bales of a continuous filamentary tow that are transported to the well site from a remote manufacturing location. At the well site, a multifilament strand can be pulled off the bale, opened, and cut to provide cut fiber segments. The cut fiber segments can be mixed with other well treatment components to create a well treatment medium that is introduced into the well as part of a drilling, stimulation, or cementing process.

Abstract: Methods of fracturing a formation including using a fracturing fluid including an aggregating composition including heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters or amine-phosphate reaction products during fracturing operations to alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials in or entrained in the fluid.

Abstract: An apparatus for measuring a well bore wall comprises a casing connectable in line with a tool string having a central passage therethrough and extending between first and second ends and a plurality of longitudinally extending biasing elements extending longitudinally along the casing between first and second ends wherein each of the second end of the biasing elements is connected to the casing. The apparatus further comprises a sensor located along a midpoint of each of the biasing elements and an engagement body located within the central passage of the casing longitudinally displaceable therein between first and second positions, wherein the engagement body is connected to the first end of each of the biasing elements such that displacement of the engagement body within the central passage from the first to the second positions compresses and radially extends the biasing elements so as to engage the sensors against the well bore wall.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to estimate a value for a mud cake parameter to provide an estimated mud cake parameter value; to generate, in a solution operation, a formation parameter value and an adjusted mud cake parameter value using the estimated mud cake parameter value; and to provide corrected galvanic tool resistivity measurements based on at least the adjusted mud cake parameter value. Additional apparatus, systems, and methods are disclosed.

Abstract: A method for operating rod pumping unit for a wellbore includes measuring a parameter of the rod pumping unit at a first location; measuring the parameter of the rod pumping unit at a second location; and subtracting the measured parameters at the second location from the measured parameter at the first location.

Abstract: This disclosure describes a method of assessing fractures in an underground formation using temperature profile measured by a DTS. The fractures can be identified by a temperature profile established by the feedback signals obtained from the DTS, but the DTS measurements are made at least 36 hours after a stage is fractured and during shut-in, thus allow crossflow and other noise sources to abate. Further, the size of the temperature differential is indicative of fracture spacing or density, not volume of fluid flow as thought in the prior art. Thus, these methods can be used to optimize the next stage or next well in a fracturing program.

Abstract: A system for tracking an object in oil and gas wellbore operations wherein a releasable object carrying a first signal system is released into tube system associated with a wellbore. The first signal system communicates with one or more second signal systems positioned along the travel path of the object; along the surface of the formation; and/or throughout the wellbore. First signal system and the second signal system may communicate by RF signals. First signal system and any second signal systems positioned on the surface communicate by through-the-earth or very low frequency signals. A global positioning system may be utilized in conjunction with any second signal systems on the surface to identify the absolute location of the object in the underground wellbore. The first signal system carried by the object may be a piezoelectric system disposed to transmit a signal when the object experiences a predetermined pressure.

Abstract: A system for tracking an object in oil and gas wellbore operations wherein a releasable object carrying a first signal system is released into tube system associated with a wellbore. The first signal system communicates with one or more second signal systems positioned along the travel path of the object; along the surface of the formation; and/or throughout the wellbore. First signal system and the second signal system may communicate by RF signals. First signal system and any second signal systems positioned on the surface communicate by through-the-earth or very low frequency signals. A global positioning system may be utilized in conjunction with any second signal systems on the surface to identify the absolute location of the object in the underground wellbore. The first signal system carried by the object may be a piezoelectric system disposed to transmit a signal when the object experiences a predetermined pressure.

Abstract: Systems, methods, and computer-readable media for providing adaptive feedback in downhole telemetry in a wellbore. A feedback system includes a source assembly, which can be located on the surface or downhole, and a receiving assembly, which can likewise be located on the surface or downhole. The source assembly includes a source device that transmits a light signal having a first phase, and an encoder coupled to the source device. The receiving assembly comprising an oscillator that transmits an oscillator having a second phase, a coupler that couples the light signal with the oscillator signal, a detector and difference amplifier that detect and determine the difference between the first phase and second phase and a processor that receives the difference between the phases and provides the difference to an encoder so that the encoder can adjust the oscillator phase.

Abstract: The present invention relates to a device for measuring a suspension in a drilling fluid and a thickness of slime at the bottom of a pile borehole, the device including: a data cable 300 insertable into the pile borehole; a slime-meter probe 200 connected to one end of the data cable 300 in such a manner as to be descended to the interior of the pile borehole by the own weight thereof to measure the thickness of the slime at the bottom of the pile borehole; and a slime-meter outer part 100 mounted on the outside of the slime-meter probe 200 in such a manner as to be movable relatively to the slime-meter probe 200 when reaches the bottom of the pile borehole.

Abstract: A method of performing a fracture operation at a wellsite is provided. The wellsite has a fracture network therein with natural fractures.

Abstract: Methods and systems for assessing permeability, porosity, and production fluids pressure or analyzing reservoir fluids in connection with a drilling operation are provided, comprising collecting from a series of depths mud gas samples and reservoir cuttings of a minimum size; allowing the cuttings to evolve a headspace gas within one or more time delays to obtain headspace gas samples; determining within the time delay carbon isotope ratio differences between the mud gas and headspace gas samples; and identifying the depths having isotope ratio differences smaller than those from nearby depths.

Abstract: A system and method is provided that determines at least one bottomhole condition during flowback operations in a well that traverses a hydraulically fractured reservoir. The system and method measure fluid properties of fluids produced at a surface-location of the well during the flowback operations. A transient fluid flow simulator determines composition and properties of fluids in the well between the surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties. At least one bottomhole condition in the well is determined based on the composition and properties of fluids in the well between the surface-location and at least one bottomhole-location of the well.

Abstract: The invention relates to a bit holder for an earth working machine, in particular a road milling machine, that comprises a bit receptacle in the region of a working side of a support member and that indirectly or directly carries an insertion projection on an insertion projection side of the support member, the support member comprising two stripping surfaces [first or second stripping surfaces] that form a stripping surface pair and are at an angle to one another. In order to achieve a stable and long-lived configuration with such a bit holder, provision is made according to the present invention that the support member comprises at least one further stripping surface that is at an angle to the two stripping surfaces of the stripping surface pair.