Abstract: A device for securing a data carrier to a tool holder is disclosed. In order to allow the data carrier to be easily secured to the tool holder in a reliable and permanent manner, the device includes a sleeve-shaped main body which has, at a first end, at least one projection projecting radially inwards and has, in the region of a second end opposite the first end, at least one projection projecting radially outwards.

Abstract: There is described a method of controlling a drilling operation. A pipe joint is determined to be entering a rotating control device (RCD). In response to determining that the pipe joint is entering the RCD, a weight-on-bit (WOB) setpoint is increased so as to increase a measured WOB. After increasing the WOB setpoint, the pipe joint is determined to be exiting the RCD. In response to determining that the pipe joint is exiting the RCD, the WOB setpoint is decreased so as to decrease the measured WOB.

Abstract: An apparatus for transmitting and/or receiving energy in a borehole penetrating a subsurface formation includes a tubular assembly having a tubing mandrel and a sleeve at least partially surrounding a circumference of the tubing mandrel, wherein the tubing mandrel includes a cavity and the sleeve defines at least a portion of an opening over the cavity. The apparatus also includes a transducer assembly disposed in the cavity and configured for transmitting and/or receiving the energy, wherein the transducer assembly upon relative movement of the tubing mandrel with respect to the sleeve is displaced radially.

Abstract: Technologies related to training machine-learning-based surrogate models for phase equilibria calculations are disclosed. In one implementation, an equation of state (EOS) for each of one or more regions of a reservoir is determined based on results of one or more pressure, volume, or temperature (PVT) experiments conducted on samples of downhole fluids obtained from one or more regions of the reservoir. Compositions of the samples of the downhole fluids are determined and spatially mapped based on interpolations between the one or more regions of the reservoir. One or more PVT experiments are simulated for the spatially mapped compositions of the downhole fluids using the determined EOS to create a compositional database of the reservoir. One or more machine-learning algorithms are trained using the compositional database, and the trained one or more machine-learning algorithms are used to predict phase stability and perform flash calculations for compositional reservoir simulation.

Abstract: A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.

Abstract: Methods and apparatus identify downhole equipment and correlate input data with the equipment to improve planning and/or inventory operations. For some embodiments, oilfield equipment or tubular goods such as drill pipe include a shaped recess along an outer circumference for receiving a tag cartridge by shrink fitting. Once tagged, detector system configurations at pipe yards may facilitate logging the presence and location of each drill pipe and correlating specific data, such as inspection data, to each drill pipe. Further, this correlation populates a database utilized to achieve other business functions such as forecasting number of additional drill pipe needed to purchase, invoicing customers according to actual tracked wear/use of the drill pipe being returned, and providing well or job specific drill string population using known history pipe joints.

Abstract: A system for drilling to a position relative to a geological boundary in a geological formation includes a sensor pack for sensing parameters associated with a drilling operation carried out in the geological formation by a drill. A data storage module stores a geological model of the geological formation and data relating to the sensed parameters, including data relating to the geological boundary. A processor module monitors the drilling operation using the sensed parameters data to locate the position of a drill bit of the drill in the geological formation and its corresponding position within the geological model. The processor module generates an end point at a defined position relative to the geological boundary. A drill controller communicates with the processor module, the drill controller controlling operation of the drill to cause the drill to cease drilling when the end point has been reached.

Abstract: Methods and devices for the execution of core drillings in a material by a drilling unit, which makes use of a drill bit, and such drill bits that are made up of a hollow cylindrical core barrel, which has an end plate at its rear end and abrasion elements, which serve the abrasion of material, at the front end as well as at least two high-pressure jet nozzles, which can be connected with a high-pressure source of a blasting medium. The high-pressure jet nozzles are arranged on the inner surface of the core barrel and/or its end plate and are oriented into the inside of the core barrel. As a result of a combined forward motion and rotation of the drill bit, a drilling core is formed from which an abrasion takes place by means of the blasting medium, whereby overburden is removed from the drill bit.

Abstract: Provided is a tunnel boring machine that can detect a wear condition of a disc cutter with a highly reliable configuration. The tunnel boring machine includes a measurement device. The measurement device is disposed behind the disc cutter mounted on a cutter head. The measurement device has a function as an acquisition unit that acquires cutting edge position data indicating a position of a cutting edge part of a cutter ring in the disc cutter. The tunnel boring machine further includes a DC discrimination unit that discriminates which one of a plurality of disc cutters is the disc cutter the cutting edge position data of which is acquired by the measurement device and a wear amount calculator that calculates a wear amount of the cutting edge part of the discriminated disc cutter.

Abstract: A method for injecting a controlled volume of liquid into a system having at least one liquid injection point includes inputting into a controller pressure measurements made at at least one position from a liquid storage device and the at least one injection point. The controller automatically causes a liquid injector to inject the liquid for a time duration corresponding to a predetermined liquid volume. The time duration is adjusted in relation to the measurements of pressure.

Abstract: A marine riser component which has an integrated fatigue damage sensor in which the sensor is adapted to be damaged by stresses and strains applied to the marine riser component, and is adapted to record said damage on the sensor. The sensor is optionally integrated into the body of the marine riser component in a location on the component that transmits fatigue loads to the sensor at a known stress concentration factor, optionally in a recess on the body, for example, in a closed recess on an outer surface of the marine riser component.

Abstract: A method for measuring asphaltene content of a crude oil is provided. In one embodiment, the method includes measuring an optical density of a live crude oil within a well and calculating a formation volume factor of the live crude oil based on the measured optical density. The method also includes determining asphaltene content of the live crude oil based on the measured optical density and the calculated formation volume factor of the live crude oil. Additional methods, systems, and devices are also disclosed.

Abstract: A sensor is configured to sense a deflection angle and to transmit a second signal representing the sensed deflection angle to a downhole control unit. The downhole control unit is configured receive signals from at least the sensor. An adjustable bent sub assembly is mechanically coupled to the power section. The adjustable bent sub assembly is configured to, while the downhole motor is in the wellbore, adjust the deflection angle to the desired deflection angle. A biasing mechanism is communicatively coupled to the downhole control unit and mechanically coupled to the adjustable bent sub assembly. The biasing mechanism is configured to, while the downhole motor is in the wellbore, actuate the adjustable bent sub assembly responsive to the downhole control unit. A locking mechanism is coupled to the adjustable bent sub assembly. The locking mechanism is configured to lock the desired deflection angle.

Abstract: Downhole ranging from multiple wellbores. In one example, multiple transmitters and multiple receivers are disposed in multiple wellbores to exchange electromagnetic signals. By implementing a full compensation technique, a computer system determines multiple compensated signals. A compensated signal is determined from a signal received from a first wellbore and a second signal received from a second wellbore. In another example, a first transmitter is disposed in a first wellbore, a first receiver is disposed in a second wellbore, and either a second transmitter or a second receiver is disposed in either the first wellbore or the second wellbore. By implementing partial compensation techniques, a computer system determines compensated signals. Using the compensated signals, the computer system determines a position of a first wellbore relative to a second wellbore, and provides the position.

Abstract: An embodiment of a method of predicting a location of one or more features of an earth formation during a downhole operation includes acquiring reference data and identifying one or more reference data sections, each reference data section corresponding to a feature of interest and having an associated depth or depth interval, deploying a drilling assembly and drilling a target borehole in the earth formation, and performing measurements during the operation by a downhole measurement device to generate measurement data. The method also includes performing one or more correlations of the one or more measurement data sections with one or more reference data sections; and predicting at least one of a depth of a subsequent feature of interest located beyond a current carrier depth and a point in time of a future event associated with the subsequent feature of interest based on the correlation.

Abstract: Methods and apparatus suitable for quickly and accurately measuring 13C levels and supporting data in an aqueous fluid reservoir. Interpreting the resulting data to indicate key factors regarding a reservoir and completion methods, including reservoir constraint, gas producibility, and completion success. A sensor and to a sensing method that evaluates the level of hydrologic constraint in aquifers occurring in unconventional reservoirs, such as shales and coals is disclosed. Specifically, Raman spectroscopy is disclosed as a sensor and a sensing method that measures the level of naturally-occurring 13C in an aqueous reservoir and compares the level of 13C to the levels typical for highly constrained and highly unconstrained reservoirs. The disclosed sensor and sensing method also monitors the level of naturally-occurring 13C in a reservoir. Also disclosed is a method of using ?13CDic to evaluate geographic areas of coal bed reservoir water having biologic methanogenic activity.

Abstract: A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both, contain a reservoir fluid. The method also includes receiving a portion of the reservoir fluid into the downhole acquisition tool and performing downhole fluid analysis using the downhole acquisition tool in the wellbore to determine at least one measurement associated with the portion of the reservoir fluid. The at least one measurement includes fluid density, optical density, or both. The method also includes using a processor of the downhole acquisition tool to obtain compressibility of the reservoir fluid based at least in part on the fluid density, the optical density, or both and determining a composition of the reservoir fluid based at least in part on the compressibility.

Abstract: A data logger comprises a mainboard and a jacketing, wherein the mainboard is covered with the jacketing, wherein the data logger is capable to be carried by said drilling fluid traveled in borehole, wherein the data in borehole is collected by the mainboard of the data logger during traveling.

Abstract: Methods and systems for controlling a drilling operation based on an MSE value calculated for a depth increment are disclosed herein. In an exemplary method, drilling parameters characterizing a drilling operation in a subterranean formation are received in a control system. The drilling parameters are used by the control system to calculate a depth-based mechanical specific energy (MSE) based on some amount of energy expended by at least a portion of a drilling assembly while drilling at least one identified depth sub-interval of a depth interval of a subterranean formation. The control system uses the calculated depth-based MSE to control the drilling operation.

Abstract: A smart legend groups plot lines that reflect the same type of drill string analysis. The smart legend includes parent level legend entries, each parent level legend entry including child level legend entries. The child level legend entries for a given parent level legend entry correspond to plot lines that reflect a particular type of drill string analysis. Each child level legend entry corresponds to a plot line that reflects the particular drill string analysis performed over a different depth range. This allows users easily to view and compare the analyses at the different drilling depth ranges.

Abstract: A method of monitoring a longwall shearing mining machine in a longwall mining system, wherein the shearing mining machine includes a shearer having a first cutter drum and a second cutter drum, includes receiving, by a processor, shearer position data over a shear cycle. The horizon profile data includes information regarding at least one of the group comprising of a position and angle of the shearer, a position of the first cutter drum, and a position of the second cutter drum. The method also includes analyzing the shearer position data, by the processor, to determine whether a position failure occurred during the shear cycle based on whether the computed horizon profile data was within normal operational parameters during the shear cycle, and generating an alert upon determining that the position failure occurred during the shear cycle.

Abstract: Downhole drilling tools designed and manufactured to minimize or reduce imbalance forces and wear by disposing cutting elements in cutter groups and cutter sets in a level of force balance and by placing impact and/or wear resistant cutters on blades subject to high impact forces and/or large loadings. Manufacturing costs may be reduced by placing inexpensive cutters on blades not subject to high impact forces and/or loadings. Some embodiments comprise designing downhole tools with combinations of thicker blades to receive high impact forces and/or loadings with thinner blades. Some embodiments comprise designing downhole drilling tools with optimized fluid-flow properties. Designing methods may comprise performing simulations on a designed tool, evaluating respective forces acting on cutters during simulated engagement with a downhole (uniform and transitional) and/or evaluating wear on cutters and bit, and/or CFD simulations to evaluate fluid-flow optimization on a tool.

Abstract: A system for wirelessly monitoring well conditions includes a set of wireless transceivers placed along a drill string inside a well, each transceiver placed within at least half the maximum distance that each transceiver can transmit data, and a power generator attached to each transceiver that powers the respective transceiver, the power generator including a first material that is of one polarity and a second material that is fixed in position and is of opposite polarity of the first material, wherein the first material is propelled toward the second material based on the motion of the power generator so that the two materials have a maximized point of contact to generate maximum power. The wireless transceivers may communicate using any wireless communication technology, including but not limited to Wi-Fi, Wi-Fi Direct, and BLE.

Abstract: A method is provided for type-specific operating of an electric drive unit, wherein the drive unit is configured for coupling and driving a tool unit selected from a set of different types of tool units. The set includes at least one rotatory tool unit and at least one non-rotatory tool unit. The method includes: driving of a coupled tool unit by the drive unit; identifying operating data of the drive unit during the driving procedure; determining, based on the identified operating data, whether the coupled tool unit is a rotatory tool unit or a non-rotatory tool unit; and controlling the drive unit in a rotation control mode if the coupled tool unit is determined to be a rotatory tool unit, or in a non-rotation control mode if the coupled tool unit is determined to be a non-rotatory tool unit.

Abstract: A tubular has a central axis and includes a first end, a second end, and a radially outer surface extending axially from the first end to the second end. In addition, the tubular includes a first end section at the first end, a second end section at the second end, and a mid-section extending axially from the first end section to the second end section. The first end section includes a first threaded portion and the second end section includes a second threaded portion. Further, the tubular includes an elongate recess extending radially inward from the radially outer surface. The elongate linear recess is positioned along the mid-section axially between the first threaded portion and the second threaded portion. The elongate linear recess has a longitudinal axis oriented parallel to the central axis of the tubular. The tubular also includes an elongate RFID tag seated in the elongate recess.

Abstract: The present disclosure provides a device for power transmission and signal transfer between the stator and the rotor of a screw drilling tool. The present disclosure can replace the wireless communication technique between the rotary steering tool and the integrated MWD/LWD, omit the upper mud generator above the rotary steering tool, and thereby realize power transmission and signal transfer between the stator and the rotor of the screw drilling tool.

Abstract: A subassembly for a bottom hole assembly of a drill string, the subassembly comprising: a tubular portion having a wall for supporting one or more sensors and an inner surface defining a longitudinal bore; a probe assembly comprising a main body, the probe assembly being removably located in the bore and positioned such that a flow channel for drilling fluid is defined between the inner surface of the tubular portion and the probe assembly. A communications link for data transfer between the probe assembly and a sensor supported by the tubular portion.

Abstract: A system for wirelessly monitoring well conditions includes a set of wireless transceivers placed along a drill string inside a well, each transceiver placed within at least half the maximum distance that each transceiver can transmit data, and a power generator attached to each transceiver that powers the respective transceiver, the power generator including a first material that is of one polarity and a second material that is fixed in position and is of opposite polarity of the first material, wherein the first material is propelled toward the second material based on the motion of the power generator so that the two materials have a maximized point of contact to generate maximum power. The wireless transceivers may communicate using any wireless communication technology, including but not limited to Wi-Fi, Wi-Fi Direct, and BLE.

Abstract: A process for directional operations in a well bore without MWD, the process comprising: engaging an upper end of a drill string with a traveling block component, wherein the traveling block component comprises a traveling block angular sensor; measuring with the traveling block angular sensor an initial angular position of the drill string; lowering the drill string in the well bore with the traveling block component; measuring with the traveling block angular sensor a final angular position of the drill string; recording an angle of rotation, if any, of the drill string between initial and final positions as measured by the traveling block angular sensor; engaging the drill string with a rig floor component, wherein the rig floor component comprises a rig floor angular sensor; measuring with the rig floor angular sensor an initial angular position of the drill string; disengaging the traveling block component from the drill string; raising the traveling block component; engaging an upper end of a first tubu

Abstract: A method for wellbore directional drilling includes selecting a starting and stopping spatial position of at least one portion of the wellbore. A sequence of sliding and rotary drilling operations within the portion is determined to calculate a wellbore trajectory. The sequence has at least one drilling operating parameter. The operations include a constraint on the drilling operating parameter or the calculated trajectory. The calculated trajectory includes a projected steering response of a steerable motor in response to the at least one drilling operating parameter. Drilling the portion of the wellbore is started. A spatial position of the wellbore during drilling is determined at at least one point intermediate the starting and stopping positions. Using a relationship between the projected steering response and the drilling operating parameter, the drilling parameter and/or the constraint are adjusted based on the measured spatial position and the stopping spatial position.

Abstract: A system includes at least one hardware processor interoperably coupled with computer memory and configured to perform operations of one or more components of the computer-implemented system. The system includes a detachable module (DM) delivery system configured to deploy, from release grooves of the NRSS and during a survey of the NRSS inside a wellbore during drilling of a well, plural DMs into an environment surrounding the NRSS, wherein the plural DMs are pre-loaded into the NRSS, and plural DMs are configured to gather and store sensing data from the environment.

Abstract: A wear resistant part includes a first material including a structure having a surface feature. The first material is capable of maintaining its structure at a temperature from about 1000° C. to about 1500° C. (e.g., upon exposure to the temperature or upon being heated to reach the temperature). The wear resistant part also includes a second material formed into a shape extending partially around the structure of the first material while exposing the surface feature of the first material. The shape of the second material is formed by a matrix infiltration at a temperature from about 1000° C. to about 1500° C.

Abstract: A high temperature downhole power generating device includes a power generator including a first material of one polarity and a second material that is fixed in position and is of opposite polarity of the first material, wherein the first material is propelled toward the second material based on motion of the high temperature downhole power generating device so that the two materials have a maximized point of contact to generate maximum power, at least one electrode that is connected to the first material or second material, a bridge rectifier connected to the at least one electrode to transform the power generated into direct current from alternating current, a storage unit for storing the power generated by the power generator, a sensor that gathers information concerning a downhole environment, and a microcontroller and transceiver unit to manage the power generated by the power generator and transmit information gathered by the sensor.

Abstract: A logging method and system for imaging forward and lateral sections of a subterranean formation. An electric dipole source generates electromagnetic field in the formation that is sensed with magnetic flux sensor that is spaced a distance away from the electric dipole source. The resulting electric dipoles can be axial or transverse, and magnetic flux sensors can sense magnetic fields oriented axially or orthogonally. The axial and transverse electric dipoles can be collocated, and magnetic flux sensors that sense axial or orthogonal magnetic fields can be collocated. Analyzing changes in the magnitude of signals sensed by magnetic flux sensors can indicate the presence and distance of bed boundaries that are ahead and lateral to the electric dipole source.

Abstract: A device for limiting the flow of drilling fluid through a section of drill string is described. The device includes a cylindrical tube with holes in its periphery. Flow enters the device through an upper end of the tube and a portion of the flow exits through the lower end of the tube. In addition, some of the flow is diverted through the peripheral holes. A valve piston is supported near the lower end of the tube by a spring of approximately constant force through its range of travel. The valve piston moves axially as the flow rate through the tube changes flow rate to ensure that a substantially constant amount of flow exits through the lower end, while the excess flow is diverted from the tube through the peripheral holes. A means of damping or stopping the axial movement of the valve piston is included in the device.

Abstract: In drilling into a subterranean formation, several factors influence the rate of penetration, including, but not limited to, the type of formation being drilled, the weight on bit, and the rotational speed of the drill bit. Disclosed are a system and method for controlling the rotational speed of a drill bit based on regulation of fluid flow to the motor driving the bit, while maintaining at least a minimum flow of fluid to the annulus to clear debris from downhole during drilling. Regulation of fluid flow to the motor and to the annulus may be accomplished utilizing a flow diverter configured to adjust a flow ratio depending on drilling conditions in order to maximize efficiency of the motor downhole during drilling.

Abstract: A top drive apparatus for facilitating communication between a computer apparatus and a device in a drill string, particularly, but not exclusively during tripping, the drill string comprising a pipe (13) having a threaded box end (140) and a pipe communication element (160) therein, the top drive apparatus comprising a top drive (30) having a main shaft (29) and a tool (101) rotationally fast therewith, the tool (101) comprising a threaded pin end (125) having a tool communication element (170) projecting therefrom, such that in use the thread does not have to be made up to obtain a communication between the pipe communication element and the tool communication element, either by induction and most optionally a physical contact therebetween to provide an electrical contact therebetween.

Abstract: Systems and methods for filtering pump interference in mud pulse telemetry are provided. A method includes receiving a monitor output, selecting an adaptive factor in an adaptive filter module, and adjusting the adaptive factor when the adaptive filter module has reached convergence. The method may further include receiving a sensor input, providing a filtered signal output, and modifying a drill configuration based on the signal output. A system configured to perform the method above is provided. A method as above further including modifying a drill configuration based on the signal output is provided.

Abstract: A method of surveying a wellbore continuously during drilling. The method includes using a drill string with a non-rotating sub-assembly. The non-rotating sub-assembly comprises three accelerometers oriented orthogonally to each other and three directional sensors also oriented orthogonally to each other. Sample measurements from the six sensors are used to calculate the attitude of the wellbore and more specifically used to create an accurate survey of wellbores within a subterranean formation while the drill string is drilling.

Abstract: A system for wirelessly monitoring well conditions includes a set of wireless transceivers placed along a drill string inside a well, each transceiver placed within at least half the maximum distance that each transceiver can transmit data, and a power generator attached to each transceiver that powers the respective transceiver, the power generator including a first material that is of one polarity and a second material that is fixed in position and is of opposite polarity of the first material, wherein the first material is propelled toward the second material based on the motion of the power generator so that the two materials have a maximized point of contact to generate maximum power. The wireless transceivers may communicate using any wireless communication technology, including but not limited to Wi-Fi, Wi-Fi Direct, and BLE.

Abstract: Tight spots in movements of a drill string in an oil well are identified by comparing a large interval hookload moving average to a short interval hookload moving average, comparing a large interval bit depth moving average to a short interval bit depth moving average, and DBSCANing the tight spots to identify a fully-stuck event.

Abstract: A system and method for drilling a borehole using a drilling rig having a rotary drill bit includes monitoring one or more drilling parameters; determining whether the one or more monitored drilling parameters are within predetermined specifications for one or more of the monitored drill parameters; and, executing an exception control procedure for control of a drilling parameter. The exception control procedure receives an input sensor value associated with a drilling parameter and applies feedback control to establish a scaled error value that is used to compute a setting value for the drilling parameter. The drilling parameters controlled may include the rotation speed of the drill bit, the feed rate of the drill bit, the weight-on-bit, or rotation torque during retraction of the drill bit. A computer-readable database of specifications of drill bits may be provided as a part of the system.

Abstract: A downhole tool includes a valve assembly and a shock absorbing assembly. The valve assembly includes a valve spring operatively connected to a valve body. The shock absorbing assembly includes a spring operatively connected to a shock absorbing body having a fluid passage therethrough. The valve body is configured to selectively engage the shock absorbing body to create a fluid tight seal over the fluid passage in a first position, and to allow a fluid flow through the fluid passage in a second position. The repeated movement cycle of the selective engagement between the valve body and the shock absorbing body generates a pressure pulse or a varying pressure differential across the downhole tool. The repeated movement cycle is powered by a fluid flow. The tool may be selectively activated and deactivated.

Abstract: The invention discloses a series of methods to design drilling trajectory and control drilling operations in a optimized way in carbonate formation. The trajectory design method comprises: utilizing earthquake data to obtain contours of the carbonate rock fractures; determining a safe distance from each carbonate rock fracture; determining a segmented drilling trajectory for each fracture or vuggy structures in carbonate formation; and sequentially connecting the segmented drilling trajectories of neighboring fracture and vuggy to obtain a smooth horizontal drilling trajectory. The invention optimizes the carbonate rock reservoir drilling trajectory, thus improving connection between a horizontal well and the fractures. This reduces development costs, increases exploration and development efficiency and, at the same time, eliminates leaks resulting from the drilling process, thereby allowing for smooth drilling to a target well depth.

Abstract: An automated hydraulic fracturing system, including a pump system, a blender configured to form the fracturing fluid, a proppant storage and delivery system, a hydration unit configured to mix an additive into a fluid to form the fluid mixture and provide the fluid mixture to the blender, a fluid storage and delivery system, and an additive storage and delivery system, and an automated control system including a plurality of sensing devices and a plurality of control devices integrated into the pump system, the blender system, the proppant storage and delivery system, the fluid storage and delivery system, and the additive storage and delivery system, the automated control system configured to monitor parameters of the automated hydraulic fracturing system via the plurality of sensing devices and transmit control instructions for one or more of the plurality of control devices to control an aspect of the automated hydraulic fracturing system.

Abstract: A drillstring comprising a length of drillpipes and a bottomhole assembly disposed at a downhole end of the length of drillpipes. The bottomhole assembly comprises a transition section proximal to the end of the length of drillpipes to reduce vibration of the bottomhole assembly during drilling. The transition section varies gradually in acoustic impedance between the acoustic impedance of the drillstring above the transition section and the acoustic impedance of the bottomhole assembly below the transition section. The transition section forms at least thirty percent (30%) of the total length of the bottomhole assembly.

Abstract: The present disclosure relates to systems, assemblies, and methods for facilitating fluid flow during/after landing of logging tools in a bottom hole assembly. In operation, a memory logging tool is lowered through a longitudinal bore of a drill pipe string and landed in a bottom hole assembly disposed at the end of the drill pipe string. Drilling fluid is pumped behind the logging tool to assist with downward movement of the tool. As the logging tools land, partial fluid flow path is blocked by the logging tools. The fluid pressure can rise in response to the narrowing of the fluid flow path. Facilitating fluid flow through and/or around the logging tools can put the rising fluid pressure in a proper range for powering the logging tools to land and monitoring purposes.

Abstract: The present disclosure generally relates to elevators and other tools having radio frequency identification (RFID) tags embedded therein to facilitate identification of the elevators. The tools include an RFID tag embedded therein to facilitate identification of the tool. The RFID tag may be disposed in a bore formed in tool, and then optionally covered with a capping material.

Abstract: A method for determining organic richness of a formation is disclosed. The method involves obtaining a microresistivity image of the formation, obtaining acoustic logging data for the formation, fusing the microresistivity image with the acoustic logging data to generate a fused pseudo-acoustic image of the formation, and determining an organic richness image based on the fused pseudo-acoustic image. The difference between the fused pseudo-acoustic image and the microresistivity image indicates organic richness.

Abstract: A method of operating a Moineau system to substantially eliminate vibrations, the method includes rotating a first rotational member, and rotating a second rotational member. Each of the first rotational member and the second rotational member includes a plurality of lobes. A first rotational speed of one of the first rotational member and the second rotational member is selected based on 1) a second rotational speed of the other of the first rotational member and the second rotational member and 2) the number of lobes of one of the first rotational member and the second rotational member to maintain eccentric force of one of the first and second rotational members below a predetermined threshold.