Abstract: A down-hole drilling apparatus includes a bearing housing defining a longitudinal axis and upper and lower portions. The upper portion of the bearing housing is configured for connection to a drill string, and at least one annular bearing package disposed within the bearing housing. A drill bit is coupled to the bearing housing and rotatable with respect to the longitudinal axis. The drill bit includes a leading body supporting a plurality of cutters thereon for engaging a subterranean rock formation, a shank portion projecting from the leading body, and a mandrel portion engaging the shank portion and defining an inseparable connection therewith. The mandrel portion extends longitudinally into the bearing housing and through the at least one annular bearing package.

Abstract: A distributed drilling simulation system includes a choke manifold, a high pressure manifold, a blowout preventer console, a choke console, a remote console, a driller console, a teacher console and a graphic projecting unit, wherein the driller console, the remote console, the blowout preventer console, the choke console, the choke manifold, and the high pressure manifold are interconnected through a PPI (processor/peripheral interface) protocol. The teacher console is connected with the PPI protocol through a PPI interface. A communication program and a main control program run on a main control computer and a graphic processing program runs on a graphic computer. The invention has the advantages of realizing high-degree top driving drilling simulation, enhancing the field sense for teaching and training, shortening the training period and reducing the training cost.

Abstract: The present application is directed to a system providing automatic and manual control of a brake lever on band brake drawworks of a wellbore drilling rig. The system comprises a pneumatic cylinder attached to the brake lever; and a control means in fluid communication with the pneumatic cylinder, the control means being operationally configured to run the pneumatic cylinder in response to information obtained by the control means concerning one or more drilling parameters and operationally configured to disable the pneumatic cylinder.

Abstract: A torque measuring device for top drives, which includes plates mounted to a top drive. A torque measuring pin and a hinge pin can be engaged with the plates and a torque slide assembly. Bosses can be connected to the top drive, and can have the torque measuring pin engaged therethrough to restrain vertical and axial movement between the plates. A boss can be connected to the top drive and engaged with the torque measuring pin to bend the torque measuring pin when torque is applied to the top drive. One or more bosses can be connected to the top drive, and can have the hinge pin engaged therethrough to hinge the plates to the top drive. A strain gauge sensor can be engaged with the torque measuring pin. A controller can be in communication with the strain gauge sensor to receive signals therefrom.

Abstract: An impact apparatus conveyable in a tool string via conveyance means within a wellbore. The impact apparatus comprises a first portion, including a first interface coupled with a first tool string component, a first engagement feature, and a first impact feature. The impact apparatus also comprises a second portion, including a second interface coupled with a second tool string apparatus, a second engagement feature in selectable engagement with the first engagement feature, and a second impact feature positioned to impact the first impact feature in response to disengagement of the first and second engagement features and a tensile force applied across the tool string by the conveyance means. A release member positionable between first and second positions in response to a signal carried by the conveyance means prevents disengagement of the first and second engaging features when in the first position but not the second position.

Abstract: In one aspect, a method of performing a downhole operation is disclosed that in one embodiment may include running a downhole tool including an anchor, a whipstock, a cutting device, and an unlocked fluid-operated motor into a wellbore; wirelessly transmitting signals relating to orientation of the downhole tool from a sensor associated with the downhole tool; orienting the whipstock in response to the transmitted signals and without flowing a fluid through the cutting device; setting the anchor in the wellbore without flowing the fluid through the cutting device; and performing the downhole operation using the motor.

Abstract: A method for motion compensation includes obtaining measurements related to heave at a surface of a rig, transmitting the measurements to a processor, automatically transmitting a control signal from the processor to a motion compensation component in response to the measurements wherein the motion compensation component is a slip joint and is attached to a drill string located in the wellbore, activating the motion compensation component to compensate for motion in response to the signal, and preventing axial or rotational movement of a portion of the drill string below the motion compensation component.

Abstract: An electrical power system comprising a support configured for interconnection within a subsurface drillstring, an electrical power unit coupled to the support, and a conductive link configured to distribute electrical power from the electrical power unit to at least one component coupled to the electrical power system within the subsurface drillstring.

Abstract: A drilling apparatus (1) provides continuous rotation, and in some embodiments also vertical translation of the drill bit, such that weight can be kept on the bit and drilling can continue uninterrupted during connections. The connection is made in a pressure chamber formed by seals (2, 4) and spacers (15, 16). An upper snubber (5) grips the drill string above the joint and a lower snubber (6) grips it below the joint. The top drive is decoupled as the snubbers take over drill string drive, and apply a differential torque so that the connection is made. This achieves continuous rotation during the connection, and by use of an extension sub (18) drilling is also continuous.

Abstract: A prog analysis and execution system and method. The system includes a computer control system, an interface engine in communication with the computer control system, the interface engine being configured to receive prog information, and an action item development engine in communication with the control system, the action item development engine being configured to analyze received prog information and to determine corresponding action items. The system further includes a sensor engine in communication with the computer control system, the sensor engine being configured to receive input from at least one sensor for use in controlling a well drilling operation, and an operational equipment engine in communication with the computer control system, the operational equipment engine being configured to receive input from the computer control system and to control the well drilling operation in accordance with the determined action items in the prog.

Abstract: An apparatus for measuring permittivity of a sample. The apparatus includes: a sample chamber including a sealed space portion in which a sample to be measured is put; a pressure adjusting unit for varying pressure by applying water pressure to the space portion of the sample chamber; a permittivity sensor for measuring permittivity of the sample and disposed outside the sample chamber; measurement conducting wires including conductors, installed to contact the sample and connected to the permittivity sensor by using electric wires; and a data logger for storing data relating to permittivity that is measured by the permittivity sensor.

Abstract: Methods and systems are described for improved drilling operations through the use of real-time drilling data to predict bit wear, lithology, pore pressure, a rotating friction coefficient, permeability, and cost in real-time and to adjust drilling parameters in real-time based on the predictions. The real-time lithology prediction is made by processing the real-time drilling data through a multilayer neural network. The real-time bit wear prediction is made by using the real-time drilling data to predict a bit efficiency factor and to detect changes in the bit efficiency factor over time. These predictions may be used to adjust drilling parameters in the drilling operation in real-time, subject to override by the operator. The methods and systems may also include determining various downhole hydraulics parameters and a rotary friction factor. Historical data may be used in combination with real-time data to provide expert system assistance and to identify safety concerns.

Abstract: Provided is apparatus for use in resonance enhanced rotary drilling, which apparatus comprises: (i) an upper load-cell for measuring static and dynamic axial loading; (ii) a vibration isolation unit; (iii) optionally an oscillator back mass; (iv) an oscillator for applying axial oscillatory loading to the rotary drill-bit; (v) a vibration transmission unit; (vi) a lower load-cell for measuring static and dynamic axial loading; (vii) a drill-bit connector; and (viii) a drill-bit, wherein the upper load-cell is positioned above the vibration isolation unit and the lower load-cell is positioned between the vibration transmission unit and the drill-bit, and wherein the upper and lower load-cells are connected to a controller in order to provide down-hole closed loop real time control of the oscillator.

Abstract: Predicting a drill string stuck pipe event. At least some of the illustrative embodiments are methods including: receiving a plurality of drilling parameters from a drilling operation; applying the plurality of drilling parameters to an ensemble prediction model comprising at least three machine-learning algorithms operated in parallel, each machine-learning algorithm predicting a probability of occurrence of a future stuck pipe event based on at least one of the plurality of drilling parameters, the ensemble prediction model creates a combined probability based on the probability of occurrence of the future stuck pipe event of each machine-learning algorithm; and providing an indication of a likelihood of a future stuck pipe event to a drilling operator, the indication based on the combined probability.

Abstract: A system and method are provided for producing controlled vibrations within a borehole. In one example, the system includes a movement mechanism and a vibration control mechanism. The movement mechanism is configured to use mechanical energy provided by a mechanical energy source to enable translational movement of a first surface relative to a second surface to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats, where the vibration beats will occur whenever the mechanical energy is provided by the mechanical energy source unless the provided mechanical energy is dampened to prevent the translational movement. The vibration control mechanism is configured to selectively control an amplitude of the vibration beats to encode information therein, where the amplitude of a vibration beat is selectively controlled by dampening the provided mechanical energy to regulate the impact of the first surface and the second surface.

Abstract: Methods and related systems are described for making an electromagnetic induction survey of a formation surrounding a cased section of a borehole. An electromagnetic transmitter and/or receiver are deployed into the cased section of the borehole. One or more additional devices are used to measure the properties of a conductive casing relating to conductivity, thickness and magnetic permeability. A casing coefficient is then calculated that can then be used for the processing of the deep-sensing induction measurements.

Abstract: A method for aggregating data for a drilling operation. The method includes acquiring the data from a number of data sources associated with the drilling operation, synchronizing a timing of the data for aggregating the data to generate synchronized aggregated data, determining a drilling context based on the synchronized aggregated data, and assigning the determined drilling context to the synchronized aggregated data. The method further includes analyzing the synchronized aggregated data in the drilling context to generate an analysis and presenting the analysis to at least one user.

Abstract: A preferred method for acquiring information during an underground drilling operation includes providing a sensing device capable of acquiring information concerning the underground drilling operation from a down-hole location on a selective basis in response to an input from the surface, and drilling for a first period of time. The preferred method also includes sending the input to the sensing device after drilling for the first period of time, and drilling during a second period of time while acquiring the information using the sensing device.

Abstract: An underground directional drilling system can comprise a plurality of elongated dual-shaft segments coupled together end-to-end in a drilling string. The segments include an inner shaft that is independently rotable relative to an annular outer shaft, with the inner shafts being coupled together and the outer shafts being coupled together. The plurality of dual-shaft segments can comprise a communication segment that comprises a first electrode, a second electrode, a gap portion between the first and second electrodes that provides electrical insulation therebetween, and an electronic communication controller electrically coupled to the first and second electrodes. The communication controller is configured to generate voltage differences between the electrodes that cause electrical pulses to periodically transfer between the electrodes through the gap portion to wirelessly communicate drilling related data from underground to the surface.

Abstract: An alert system for a downhole operation including a tubular string in a borehole. The tubular string having at least one sensor positioned in the borehole for measuring at least one parameter during operation of the tubular string. A unit in data communication with the tubular string and operatively arranged to enable an operator to obtain information regarding operation of the tubular string. A work area positioned proximate to the unit and operatively arranged to receive the operator when the operator is interfacing with the unit. A vibration module operatively arranged to vibrate the work area or a structure therein, wherein the vibration module is triggered in response to a first parameter being outside of a predetermined range set by a first threshold value. Also included is a method of alerting an operator during a drilling operation.

Abstract: A drill bit made according to one embodiment includes a source configured to induce radiation into a formation during drilling of a wellbore and a sensor in the drill bit configured to detect radiation from the formation responsive to the radiation induced by the source. The drill bit may further include a circuit configured to process signals received from the sensor to estimate a property of the formation.

Abstract: A coupling adapter is insertable in at least one joint of a drill string as the drill string is extended from a drill rig. The coupling adapter includes an arrangement for receiving a data signal that is generated by an inground tool and for electromagnetically coupling the data signal onto at least a portion of the drill string that extends from the adapter to the drill rig such that at least some of the drill pipe sections cooperate as an electrical conductor for carrying the data signal to the drill rig. In another feature, a current transformer is resiliently supported to isolate the current transformer from mechanical shock and vibration that is produced by an inground operation that is performed using the drill string. In another feature, a drill string repeater is described.

Abstract: A method and equipment for displaying holes to be drilled when drilling holes into rock with a rock-drilling rig having control equipment and a display belonging thereto and measuring means for defining the direction and position of a drill rod, by using a pre-designed drilling plan defined in a three-dimensional coordinate system, in which a starting point (19a to 21a) and end point (19b to 21b) is defined for each hole to be drilled. A base plane running through the end point (19b to 21b) of the hole and parallel to the projection plane is defined for each hole (19 to 21), and a projection of the intersection of a hole or its extension created when drilling in accordance with the current location of the drill rod and the defined base plane is displayed with a graphical location symbol on the projection plane.

Abstract: A system and method for monitoring underground drilling in which vibration is monitored by creating a model of the drill string using finite element techniques or finite difference techniques and (i) predicting vibration by inputting real time values of operating parameters into the model, and then adjusting the model to agree with measured vibration data, (ii) predicting the weight on bit and drill string and mud motor speeds at which resonance will occur, as well as when stick-slip will occur, so that the operator can avoid operating regimes that will result in high vibration, (iii) determining vibration and torque levels along the length of the drill string based on the measured vibration and torque at one or more locations, (iv) determining the remaining life of critical components of the drill string based on the history of the vibration to which the components have been subjected, and (v) determining the optimum drilling parameters that will avoid excessive vibration of the drill string.

Abstract: A logging while drilling (LWD) caliper includes a drill collar, at least one movable pad, a hinge coupler, a power transmitter and a power receiver. The hinge coupler couples the movable pad to the drill collar in such a way that the movable pad can move between an open position and a closed position. The power transmitter is coupled to the drill collar in such a way that the power transmitter receives power from the drill collar. The power receiver is coupled to the movable pad in such a way that the power receiver provides power to the movable pad. Also, the power transmitter is coupled to the drill collar and the power receiver is coupled to the movable pad is such a way that power is transmitted from the power transmitter to the power receiver.

Abstract: Various embodiments of methods and systems for wireless power and data communications transmissions to a sensor subassembly below a mud motor in a bottom hole assembly are disclosed. Power and/or communications are transmitted through stationary or fixed coils. By leveraging resonantly tuned circuits and impedance matching techniques for the stationary coils, power and/or communications can be transmitted efficiently from one stationary coil to the other stationary coil despite any vibration and/or misalignment of the two coils.

Abstract: Provided is an apparatus for use in resonance enhanced rotary drilling, which apparatus comprises one or both of: (a) a vibration isolation unit; and (b) a vibration transmission unit. typically wherein the vibration isolation unit and/or the vibration transmission unit comprise a spring system comprising two or more frusto-conical springs arranged in series.

Abstract: Various embodiments of methods and systems for providing wireless power and data communication in a drilling assembly. One embodiment includes a system for transmitting power or data communications in a drill string. The system includes a drilling assembly having an inner cylindrical coil located inside an outer cylindrical coil. The inner cylindrical coil is adapted to rotate with respect to the outer cylindrical coil, rotate around an axis of the outer cylindrical coil, or move axially with respect to the outer cylindrical coil.

Abstract: A tool and associated methods for transmitting electromagnetic data telemetry from a downhole sensor during drilling operations. The tool may include a pressure housing, the pressure housing including an EM transmitter, receiver, or transceiver. A conductive element electrically coupled to the EM transmitter, receiver, or transceiver is positioned between an upper and a lower signal conductor positioned coaxially around the conductive element. The upper and lower signal conductors support the pressure housing and conductive element within the inner diameter of a drill collar and provide electrical connection between the conductive element and a section of the drill collar on either side of an insulated gap. In some embodiments, the conductive element is tensioned between the upper and lower signal conductors.

Abstract: A bottom hole assembly (BHA) configured for use in a drill string of a wellsite drilling system. The BHA includes a measuring-while-drilling (MWD) module, a wireless power and data connection, and a rotary steerable system (RSS). The MWD module is configured for coupling to a drill string, and includes a power generation component and a direction and inclination (D&I) survey package. The wireless power and data connection is disposed above a drilling motor in the drill string and for providing power and data connectivity between the MWD module and the drilling motor. The RSS is coupled to the drilling motor for receiving power from and communicating with the MWD module via the wireless power and data connection and the drilling motor.

Abstract: A drilling apparatus has a chassis and a feed beam. The feed beam includes a rock drill hammer, a moveable drill string, a rock drill system coupled to the feed beam, a media pressure system coupled to the rock drill system, and a sensor system. The media pressure system includes a high pressure supply path, a low pressure return path, a control valve coupled to the high pressure supply path, at least one accumulator, and a sensor system. The sensor system includes a pressure transducer coupled to the high pressure supply path, the low pressure return path, or the accumulator to supply pressure data, a control unit configured to monitor and compare the pressure data to an acceptable pressure range stored in memory, and a warning apparatus configured to alert the operator of a pressure outside of the predetermined acceptable pressure range.

Abstract: A method of forming a wellbore is provided that in one embodiment includes conveying an inner string and an outer string downhole; attaching the inner string to the outer string at a first location and forming the wellbore; and attaching the inner string to the outer string at a second location uphole of the first location and cementing an annulus between the outer string and the wellbore, without retrieving the inner string from the wellbore.

Abstract: A system transmits a wireless power transmission from a bottom hole assembly of a drill string. The system has a downhole component having a wireless power transmitter adapted to wirelessly transmit at least one wireless power transmission and a wireless power receiver adapted to receive the at least one wireless power transmission.

Abstract: A top drive assembly that includes a gauge for measuring strain in a linkage coupling the top drive to a drilling rig frame. The strain measuring gauge, which can be a strain gauge, is disposed on a pin that pivotingly links members of the linkage coupling. When a motor in the top drive assembly operates to rotate an associated pipe string, the torque generated by the motor can be estimated by monitoring strain measured in the pin.

Abstract: Oilfield drilling utilizes downhole data transmitted to surface for formation evaluation and steering of directional wellbores. A leading technology in providing subsurface to surface communication is Electro-Magnetic (EM) Telemetry. This technology is typically employed with a downhole antenna concentric with the bore of an electrically insulating “gap sub” portion of the system. The antenna blocks the bore from further use to conduct other sensors or equipment through. One aspect of the invention is to integrate the antenna into the structure of the gap sub, thereby clearing the bore for conducting other tools through, and also protecting the antenna from the harsh drilling environment, including abrasion, erosion, shock, and vibration. Another aspect of this invention enables the antenna to serve a secondary function as an anti-rotation feature between the two halves of the gap sub.

Abstract: A rotation unit, rock drilling unit and method for rock drilling. The rotation unit includes a main shaft that is rotated around its longitudinal axis by means of a rotating motor. The main shaft is supported on a body of the rotation device slidingly in the axial direction. This slide property is utilized when connection threads of drilling equipment and drilling components comprised by it are connected.

Abstract: A system and method for monitoring underground drilling in which vibration is monitored by creating a model of the drill string using finite element techniques or finite difference techniques and (i) predicting vibration by inputting real time values of operating parameters into the model, and then adjusting the model to agree with measured vibration data, (ii) predicting the weight on bit and drill string and mud motor speeds at which resonance will occur, as well as when stick-slip will occur, so that the operator can avoid operating regimes that will result in high vibration, (iii) determining vibration and torque levels along the length of the drill string based on the measured vibration and torque at one or more locations, (iv) determining the remaining life of critical components of the drill string based on the history of the vibration to which the components have been subjected, and (v) determining the optimum drilling parameters that will avoid excessive vibration of the drill string.

Abstract: An apparatus, a system and a method for motion compensation use wired drill pipe to transmit downhole measurements from downhole tools to the surface. The wired drill pipe may transmit control signals from a terminal located at the surface to the downhole tools. In response to the control signals, a motion compensation component may enable the drill string to compensate for motion, such as, for example, heave. The motion compensation component may change a length of the drill string. A downhole tool having arms may be connected to the drill string and the wired drill pipe. The control signals may direct the downhole tool to move between an extended position and a retracted position.

Abstract: In one aspect, a drill bit is disclosed that in one embodiment includes a pad configured to extend and retract from a surface of the drill bit, and a force application device configured to extend and retract the pad, wherein the force application device includes a screw driven by an electric motor that linearly moves a drive unit to extend and retract the pad from the drill bit surface. In another aspect, a method of drilling a wellbore is provided that in one embodiment includes: conveying a drill string having a drill bit at an end thereof, wherein the drill bit includes a pad configured to extend and retract from a surface of the drill bit and a force application device configured to extend and retract the pad, wherein the force application device includes a screw driven by an electric motor that moves a drive unit to extend the pad from the drill bit face; and rotating the drill bit to drill the wellbore.

Abstract: In one aspect, a drill bit is disclosed that in one embodiment includes a pad configured to extend and retract from a surface of the drill bit and a force application device configured to extend and retract the pad, wherein the force application device includes a force action member that includes a lever action device configured to extend and retract the pad from the drill bit surface. In another aspect, a method of drilling a wellbore is provided that in one embodiment includes: conveying a drill string having a drill bit at an end thereof, wherein the drill bit includes a pad configured to extend and retract from a surface of the drill bit and a force application device that includes a lever action device configured to extend and retract the pad from the surface of the drill bit; and rotating the drill bit to drill the wellbore.

Abstract: A method of monitoring downhole conditions in a borehole includes receiving sensor data through a network of nodes provided at selected positions on a drill string disposed in the borehole. An inference is made about the downhole condition from the sensor data. A determination is made whether the downhole condition matches a target downhole condition within a set tolerance. At least one parameter affecting the downhole condition is selectively adjusted if the downhole condition does not match the target downhole condition within the set tolerance.

Abstract: A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs.

Abstract: Systems, apparatus and methods are described for purposes of initiating a response to detection of an adverse operational condition involving a system including a drill rig and an inground tool. The response can be based on an uphole sensed parameter in combination with a downhole sensed parameter. The adverse operational condition can involve cross-bore detection, frac-out detection, excessive downhole pressure, a plugged jet indication and drill string key-holing detection. A communication system includes an inground communication link that allows bidirectional communication between a walkover detector and the drill rig via the inground tool. Monitoring of inground tool depth and/or lateral movement can be performed using techniques that approach integrated values. Bit force based auto-carving is described in the context of an automated procedure.

Abstract: A spindle for a mud pulse telemetry tool includes a seal section having an outer surface for contacting a lip seal of a spindle housing in which the spindle is mounted; a top section attachable to at least part of a valve assembly for generating mud pulses; and a base section having a proximal end attachable to a drive motor for moving the spindle and a distal end attachable to the top section such that the annular seal is fixed between the top and base sections. The seal section can be made of a ceramic material such as yttrium-stabilized zirconia.

Abstract: An apparatus for downhole operation. The apparatus comprising a support body having a surface located in a borehole and a coating on an at least a portion of the surface of the support body. The coating is an inert material selected for reducing friction and corrosion.

Abstract: A drilling rig with a top drive having a torque measuring load cell made from a strain gauged bending pin. When the unit torques up, the bending pin can be arranged to bend slightly in proportion to torque, and a strain gauge on the bending pin provides measurement that can be calibrated electronically in foot-lbs of torque.

Abstract: A method and apparatus for detecting a kick in a wellbore using acoustic transducers. In one embodiment, a system for detecting a kick in a wellbore includes a drill string having a plurality of sections of drill pipes and a plurality of kick detection subs disposed between the sections of drill pipes. Each of the kick detection subs includes an acoustic transducer and kick detection circuitry coupled to the acoustic transducer. The kick detection circuitry is configured to detect gas bubbles in the wellbore based on acoustic signals received by the acoustic transducer. The kick detection circuitry is also configured to determine whether a kick is present in the wellbore based on the detected gas bubbles. The kick detection circuitry is further configured to transmit information indicating whether a kick is present to the surface.

Abstract: A method for drilling operation in a subterranean formation, including calculating, by a hardware processor and in response to determining that an magnitude of gyro data representing rotations of a drill bit in a bottom hole assembly (BHA) and a time derivative of the gyro data are within a pre-determined range, a drift parameter of the gyro data, analyzing, by the hardware processor, the gyro data based on the drift parameter to generate a stick-slip alert, and presenting the stick-slip alert.

Abstract: A method can include proposing a new well; accessing data associated with at least one other well where at least a portion of the data includes indicia of uncertainty; performing a geostatistical analysis of the accessed data for an issue for drilling of the new well to provide a probability of occurrence for the issue and an uncertainty for the accessed data; and rendering to a display a graphical representation of the well, the probability of occurrence for the issue and the uncertainty for the accessed data as a function of depth. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A method for managing a drilling operation, including generating, by a first sensor and a second sensor of a bottom hole assembly (BHA), a first time based data log and a second time based data log, respectively, representing a borehole parameter along a drilling trajectory, determining, by a computer processor of the BHA and during the drilling operation, a time shift by comparing the first time based data log and the second time based data log, where offsetting the first and second time based data logs by the time shift maximizes a correlation factor of the first and second time based data logs, and determining, within a pre-determined time period from generating the first and second time based data logs, a drilling speed based on the time shift and a pre-determined distance between the first sensor and the second sensor.