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 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: 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 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 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: 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: 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: 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: 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 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.

Abstract: A connector or connector assembly (10, 210), such as a subsea or underwater connector or assembly including a first member (18, 218) movably connected or connectable to a second member (36, 236) and a first inductive element (24, 224a) provided on the first member (18, 218), the first inductive element (24, 224a) being arranged for inductive transmission and/or reception with a second inductive element (42, 242a) of the second member (36, 236). The first member (18, 218) may rotatably or pivotably connected or connectable to the second member (36, 236). The first inductive element (24, 224a) may be arranged on the first member (18, 218) to maintain inductive transmission with the second inductive element (42, 242a) of the second member (36, 236) throughout movement of the first member (18, 218) relative to a second member (36, 236).

Abstract: Methods and apparatus for toolface control are disclosed herein. Such toolface controls may be provided responsive to measurement-while-drilling (MWD) data. A dynamic model of the drilling apparatus may be constructed and estimations of one or more characteristics of the drilling apparatus (e.g., toolface orientation) may be determined from the dynamic model. MWD data may be periodically received and an error factor may be determined from the estimation and the MWD data. The dynamic model may be adjusted and an updated estimation may be determined from the updated dynamic model. Data from the determinations using the dynamic model and/or the updated dynamic model may be used to control operation of the drilling apparatus and adjust one or more operational parameters of the drilling apparatus responsive to updated estimations.

Abstract: An apparatus for controlling a downhole tool comprises a generator for generating electricity; a rotor connected to the generator; an electronic circuit electrically connected to the generator; a sensor for sensing movement of the rotor, the sensor being electrically connected to the electronic circuit; and a valve for wellbore fluid and for activating or deactivating a tool or function of the downhole tool, the valve being controllable by being electrically connected to the electronic circuit. The generator is configured to generate electricity to at least the electronic circuit when a flow of wellbore fluid drives the rotor. A corresponding method of controlling a downhole tool comprises configuring the electric circuit to open or close the valve depending on a variation or pattern of a flow rate, controlling the downhole tool.

Abstract: The present invention is a method and apparatus used to transmit information to the surface from a subsurface location during the process of drilling a bore hole comprising a pressure pulse generator or “pulser” coupled to a sensor package, a controller, an active electromagnetic system for subsurface collision avoidance, and a battery power source all of which reside inside a short section of drill pipe close to the bit at the bottom of the bore hole being drilled wherein the apparatus or “MWD Tool” can be commanded from the surface to make a measurement of desired parameters and transmit this information to the surface by encoding data in pressure pulses generated by a pulser valve that includes a stator and a rotor which may be open and closed to create pressure pulses.

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: In the field of seismic data analysis, the problem of estimating features of a microseismic event waveform, detected at the sensors of a geophone array in the presence of background seismic energy and sensor noise, is considered. Embodiments of the present disclosure provide a method and system for estimating wavefront arrival times and polarizations across the sensors of an array, while simultaneously extracting the associated event sensor waveforms from the seismic background. The resulting waveform estimates are estimated in such a way that estimation errors are expected to be noise-like, and free of any systematic changes in the magnitude or phase of the arriving wavefronts.

Abstract: Upper and lower asphaltene weight fractions of fluid proximate ends of an oil column are obtained based on measured OD. Upper and lower maltene partial densities are obtained based on the asphaltene weight fractions. A maltene partial density distribution is obtained utilizing the maltene partial densities and a predetermined diffusion model. An asphaltene partial density distribution is obtained based on the maltene partial density distribution and an estimated mass density gradient. An asphaltene weight percentage is obtained based on the asphaltene partial density distribution and the mass density gradient. The asphaltene weight percentage distribution is converted to an OD distribution utilizing a predetermined correlation. An optimization then reduces differences between the OD distribution and the measured OD data to within a predetermined range to refine a biodegradation time of the predetermined diffusion model. A viscosity distribution may be obtained based on the optimized OD distribution.

Abstract: A system and method for providing information regarding the tortuosity of a wellbore path is provided. The method includes receiving data from a plurality of survey stations of a wellbore survey. The method further includes defining a plurality of reference lines for the wellbore path. The method further includes determining a plurality of displacements of the wellbore path from the plurality of reference lines.

Abstract: A formation sampling method includes disposing a downhole tool that has an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation, pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore, detecting arrival of the heavy oil at the wellbore, and performing formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore.

Abstract: A buoyant airfoil stabilization platform that can compensate for fluid flow above, below, and around an attached payload. The airfoil stabilization platform being a substantially delta or linear shaped airfoil. The airfoil uses fluid dynamics principles to assist in the stability of a mounted payload. The airfoil stabilization platform also comprises a payload mount and a handle grip. The payload mount is designed to receive camera, lighting, sonar, and other devices. The handle grip allows the user to control and assist in the stabilization of the platform. The handle grip can further contribute to the stabilization of the platform by including components for allowing the center of gravity or buoyancy of the apparatus to be adjusted. The airfoil stabilization platform can further include winglets to assist with stabilizing the platform. In addition, lights, camera, lasers, levels, and other features may be built into the airfoil, winglets, or attached expansion pods.

Abstract: An autonomous downhole power generation system includes a power generation device configured to be disposed in an annular space around a portion of a production tubing. The power generation device is switchable between a power generation mode and a bypass mode. The system further includes a power storage device electrically coupled to the power generation device and configured to store power generated by the power generation device, and a control processor communicatively coupled to the power generation device. The control processor switches the power generation device between the power generation mode and the bypass mode based on a preprogrammed operational protocol.

Abstract: A method for measuring load performance of a positive displacement motor (PDM) test coupon. The test coupon comprises a partial length of a PDM stage and is received inside a sealable test chamber. In some embodiments, the test coupon may be cut from a failed PDM stage. The test chamber is filled with test fluid. In some embodiments, the test fluid may be drilling fluid sampled from a live well. Rotation of the rotor on the test coupon actuates rotation of the stator. A braking torque is applied to the stator rotation, enabling evaluation of, for example, fatigue load performance of test coupon. Additional embodiments comprise the rotor axis and the stator axis being offset in order to simulate rotor/stator eccentricity in a full size PDM stage.

Abstract: A system or apparatus for use in downhole communication or detection comprises a downhole arrangement defining a throughbore and primary and secondary elements. One of the primary and secondary elements is provided on the downhole arrangement and the other of the primary and secondary elements is provided in the throughbore. The primary and secondary elements are configurable for coupling of an electromagnetic field therebetween. The primary or secondary element which is provided in the throughbore may be provided on a tool such as a shifting tool which is deployable through the throughbore. The secondary element may be configured to provide the electromagnetic field coupled between the first and second elements with one or more characteristic features. The system may be configured for use, in particular though not exclusively, for communicating information to and/or from a downhole tool in an oil or gas well.

Abstract: Systems and methods for optical communication in a downhole tool are disclosed. An optical communication system includes a rotation-varying outer housing that is at least partially rotationally decoupled from an inner member. The inner member is at least partially disposed within the rotation-varying outer housing. The optical communication system also includes one or more transceiver modules, one or more transmitting bulbs rotationally coupled to one of the outer housing or the inner member, and one or more optical sensors rotationally coupled to one of the outer housing or the inner member. The transmitting bulbs are configured to transmit light over at least a portion of a cavity between the transmitting bulbs and the optical sensors, and the optical sensors are configured to receive light over at least a portion of a cavity between the transmitting bulbs and the optical sensors.

Abstract: A system for performing an operation in a wellbore comprises a tool (4) configured for deployment within the wellbore on an insulated slickline (6), and a winch (26) for hauling in and/or paying out the slickline. The system further comprises a winch controller (34) which is configured to receive information transmitted electrically from the tool along the slickline and to control the winch according to the received information. The tool may comprise a downhole tractor. The tool may comprise an electrical generator tool or a tool for performing a mechanical operation within the wellbore.

Abstract: Some system embodiments include: a casing string having a distal end with a latch assembly; and a drillstring latched within the casing string by the latch assembly, the drillstring having at least one tool for perforation and stimulation. A pressure while drilling tool and one or more packers may be provided in the drillstring to further enable the stimulation operation. Prior to perforation, the casing string is cemented in place via a cement valve, and the drillstring is unlatched and raised to the desired completion position. The perforation and stimulation process can be repeated to provide multiple completions. The drillstring can be removed from the borehole or seated in place to control production. Logging instruments can be included for steering and/or use in making completion decisions.

Abstract: A depth range manager provide users with a way to run and retain multiple depth range analyzes for a drill string operation, including the operational parameters for each analysis. This allows users easily to view and compare the analyzes at the different drilling depth ranges. In some embodiments, instead of drilling depth ranges, users may also urn and retain multiple different models and analyzes using multiple different drilling times. The operational parameters for the multiple different models and analyzes may be defined and stored using a flexible one-to-many database structure that accommodates the different sets of operational parameters as well as any existing single-analysis parameters associated with legacy analyzes. A graphical interface allows users easily to define and store the operational parameters in the flexible one-to-many database structure.

Abstract: Provided is a time-shift retransmission system which is a system that manages communication of a remote sensor connected to a communication line, the time-shift retransmission system including: a) temporary storage means in which measurement values measured according to a sampling schedule by the remote sensor is temporarily stored at a predetermined interval; and b) retransmission means that retransmits the measurement values according to a retransmission schedule with plural different cycles, in which a delay time from the measurement to the retransmission differs according to the cycle, and the delay time is set in a range in which the data amount of a measurement value group that is temporarily stored within the delay time falls within the storage capacity of the temporary storage means.

Abstract: Calculating wellbore energy. At least some of the illustrative embodiments are methods including: calculating an expected wellbore energy for a planned wellpath, the calculating by a computer system; calculating an expected tortuosity of the planned wellpath; calculating a first value indicative of probability of occurrence of a drilling event for drilling along the planned wellpath, the first value based on the expected wellbore energy and the expected tortuosity; and then drilling a wellbore along at least a first portion of the planned wellpath if the first value indicates the probability of the drilling event is less than a predetermined threshold.

Abstract: A piping is provided with an RFID tag for identifying the piping, wherein the piping comprises a first end section for being coupled to a second piping and a second end section for being coupled to a third piping. The piping further comprises a mid-section in between the end sections. The RFID tag is provided in an elongate recess that is formed in the piping and that extends in a tangential direction parallel to a surface of the mid-section of the piping.

Abstract: Transceivers and methods able to recover within less than 1 millisecond from quality degradation in the transceiver's operating point, including: receiving a signal from a second transceiver, using an adaptive digital equalizer and canceller (ADEC) to generate a slicer input signal, and generating slicing decisions and slicing errors that are used to adapt the ADEC. Shortly after identifying quality degradation in the transceiver's operating point, indicating the second transceiver to transmitting known data. And within less than 1 millisecond from identifying the quality degradation, the transceiver utilizes the known data to improve the accuracy of the slicing errors, which enables fast adaptation of the ADEC that improves the quality in the transceiver's operating point to a level that enables the transceiver to indicate the second transceiver to transmit data.

Abstract: A method and apparatus for simulating drilling operation consists of a cylindrical cell assembly (80) capable of withstanding high pressure and high temperature with a movable drill bit (27) abrading a solid sample (28) while submerged in a liquid sample (74). A loading device (42) moves a bottom shaft (46) supporting the solid sample (28) as said solid sample (28) abrades and is moved upwards, and its movement is measured by a displacement sensor (40). Liquid sample (74) is drained through solid sample (28) into receiver (38) to measure filtration of solid sample (28). Heat is provided via a heater (64) and pressure is controlled via pressurization media (72).

Abstract: An assembly usable with a bottom hole assembly in a wellbore can include a fixed housing member coupleable to a bent housing member at a housing coupling location. The bent housing member can rotate relative to the fixed housing member and can include an offset opening for receiving a drive shaft. The assembly can include an RFID tag positioned on a piston that is slideably positioned within the fixed housing member. An RFID reader can be positioned on the fixed housing member for detecting the RFID tag in response to the RFID tag being in a detectable range of the RFID reader. The RFID reader can also be for transmitting information about the RFID tag for controlling a motor to rotate and position the drive shaft at a selected angular position.

Abstract: An embodiment includes a downhole tool with first and second modular connectors. The connection modules are configured to aid make-up and assembly and improve stability during use.

Abstract: A telemetry tool comprising a pulser assembly, a primary seal, a fluid pressure pulse generator and a secondary seal. The pulser assembly comprises a housing and a driveshaft extending out of an opening in the housing. The primary seal surrounds and seals against the driveshaft to seal the opening in the housing. The fluid pressure pulse generator comprises a stator with a bore therethrough configured to fixedly attach to the housing or to a drill collar surrounding the fluid pressure pulse generator, and a rotor fixedly attached to the driveshaft. The driveshaft and rotor rotate relative to the fixed stator to generate pressure pulses in mud flowing through the fluid pressure pulse generator. The secondary seal is seated in the stator bore and surrounds and seals against a portion of the driveshaft extended out of the housing or a portion of the rotor to reduce the amount of mud, grit and debris impinging on the primary seal which could otherwise cause wear or damage the primary seal.

Abstract: An installation for intervention in a well, comprises a lower assembly comprising a neutron generator and a power source electrically connected to the neutron generator; a surface assembly comprising one or more safety devices, each safety device being either in a safe state or an unsafe state; and a communication module that connects the lower and surface assemblies. The surface assembly also comprises a surface transmitting device for transmitting data to the downhole assembly via the communication module including a first transmitter for transmitting an activating command, where the first transmitter transmits the activating command only if each of the safety device is in a safe state, and a second transmitter for transmitting a stopping command, where the second transmitter transmits the stopping command if one of the safety device is in an unsafe state.

Abstract: Well completion technology for resisting imbibing frack fluid into an inner surface of a frack comprises pumping a frack fluid into the wellbore to form a fracture in a formation surrounding a wellbore. In one example, formation of transverse micro-fractures extending transverse to the fracture is resisted to resist absorption of the frack fluid into the formation through the inner face of the fracture, or into existing transverse micro-fractures or transverse micro-fractures formed by the pumping of the frack fluid. In another example, a sealer is added to a frack fluid to sealing or coating an inner face of the fracture with the sealer. In another example, micro-particles with a size less than 100 microns are added to the frack fluid.

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: Apparatus and methods for monitoring and processing wellbore data are disclosed. An integrated digital ecosystem comprises an applied fluid optimization specialist and one or more sensors communicatively coupled to the applied fluid optimization specialist. The applied fluid optimization specialist receives data relating to performance of subterranean operations from the one or more sensors and interprets the data received. The applied fluid optimization specialist then regulates the performance of subterranean operations based on the interpretation of the data received.