Abstract: A telemetry tool assembly for exploiting subsurface fluids and minerals through well construction and production. The assembly comprises a tube comprising a bore and a bore wall and first end and a second end. The respective ends each comprise internal and external upset portions welded to a pin end tool joint or box end tool joint, respectively. The upset portions comprise an internal and external conical transition section intermediate the respective tool joints and the tube. The internal conical transition section comprises at least one socket comprising a removeable cover and side and bottom surfaces within the internal conical transition section. The socket and cover comprise a seal between the cover and socket side walls. A sensor module comprising electrical equipment is disposed within the one or more sockets and the assembly comprises a wired drill pipe (WDP). The socket surfaces comprise a hardness greater than the internal transition section.

Abstract: An obstruction relief tool can include a plurality of walls that includes an inner wall, where the inner wall forms a cavity along a length of the inner wall. The obstruction relief tool can also include a chamber disposed between the plurality of walls, where the chamber has a proximal end and a distal end. The obstruction relief tool can further include an actuation device that is configured to actuate when an obstruction is within the cavity, where the actuation device, when actuated, is configured to open a first aperture in the inner wall that leads to the proximal end of the chamber, where the distal end of the chamber leads to a second aperture in the inner wall, where the first aperture is adjacent to the cavity above the obstruction, and where the second aperture in the inner wall is adjacent to the cavity below the obstruction.

Abstract: A fluid properties sensing system includes an optical sensor which generates a sensor signal based on received laser light, a light source which transmits laser light through a transmitting fiber to a sensor head, a receiver that detects a portion of the laser light from a receiving fiber through an evanescent field of the transmitting fiber when the laser light radiates through a transmitting fiber wall of the transmitting fiber and interacts with a fluid medium at an interface of the sensor and the fluid medium, and a processor. The fibers are coupled at one end through the evanescent field to form the sensor head disposed in a flow field and to interact with the fluid medium. The processor identifies a change in the sensor signal based on a detected portion of the laser light resulting from an interaction of the sensor head with the fluid medium.

Abstract: An electronics module or “puck” is positioned in a recess formed in the outer surface of a downhole tool. The puck body includes a flange segment having a first outer diameter, and an adjacent seal-engaging segment having an outer diameter that is less than the outer diameter of the flange segment. An annular seal is disposed about the seal-engaging segment and seals between the puck and the perimeter wall of the recess. A cover ring is disposed over an intermediate segment of the puck body, capturing the seal between the cover and the flange segment. A retainer ring is employed to selectively engage and disengage the perimeter wall of the recess, retaining the puck, seal and covering ring in the recess. A method for installation and removal of the puck is disclosed.

Abstract: Systems and methods are described for determining the lag time and origin of particles in entrained in a mud stream. A size and shape of the particles may be evaluated at the surface with a visual inspection system, which permits a settling rate to be determined for each of the particles in a non-Newtonian mud stream. Together with an analysis of the pumping schedule, mud properties, trajectory of the wellbore and other fluid dynamics associated with a wellbore operation, an origin of the each of the particles from within the wellbore may be determined. At least one operational parameter for the wellbore operation may be adjusted based on the determined origin of the particles. For example, a clean-out procedure may be initiated if it is determined that particles are settling in an undesirable location in the wellbore.

Abstract: The use of an environmental sensing wireline standoff may improve operations during borehole logging procedures. An environmental sensing wireline standoff may comprise a lower body, an upper body, and a cable insert. The cable insert may further comprise a first segment and a second segment, wherein the cable insert is disposed between the lower body and the upper body, and wherein the cable insert is configurable to clamp directly onto a wireline cable. The environmental sensing wireline standoff may further comprise a sensor package. A method of assembling an environmental sensing wireline standoff may comprise securing a first segment of a cable insert into a lower body, securing a second segment of the cable insert into an upper body, attaching the sensor package to the upper body, and securing the lower body to the upper body.

Abstract: Cyber-physical systems depend on sensors to make automated decisions. Resonant acoustic injection attacks are already known to cause malfunctions by disabling MEMS-based gyroscopes. However, an open question remains on how to move beyond denial of service attacks to achieve full adversarial control of sensor outputs. This work investigates how analog acoustic injection attacks can damage the digital integrity of a popular type of sensor: the capacitive MEMS accelerometer. Spoofing such sensors with intentional acoustic interference enables an out-of-spec pathway for attackers to deliver chosen digital values to microprocessors and embedded systems that blindly trust the unvalidated integrity of sensor outputs. Two software-based solutions are presented for mitigating acoustic interference with output of a MEMS accelerometer and other types of motion sensors.

Abstract: The disclosure provides a drill bit having integrated sensors, a penetration monitoring system for a subterranean drill bit, and a method of drilling a borehole in a subterranean formation. In one example, the drill bit includes multiple blades configured to penetrate a subterranean formation, and at least one sensor, is integrated with the drill bit, that is configured to collect penetration data in real time during operation of the drill bit. An example of the method includes operating a drill bit in a borehole, receiving penetration data from the operating drill bit, wherein the penetration data is from at least one sensor integrated with the drill bit, and modifying drilling parameters of the drill bit based on the penetration data. The method can be for an open hole sidetrack.

Abstract: Disclosed embodiments include a gamma logging detector assembly that includes a detector support structure comprising one or more high density alloy materials and including a first cylindrical drill collar segment and a second cylindrical drill collar segment each having a radius of at least R1. A third cylindrical drill collar segment is disposed axially between the first and second cylindrical drill collar segments to form an annular channel over the third cylindrical drill collar segment and between the first and second cylindrical drill collar segments. The third cylindrical drill collar segment includes an inwardly defined open cavity and a radius, R2, that is less than R1. An annular pressure sleeve comprising one or more low density alloy materials is disposed within the annular channel.

Abstract: A downhole logging tool includes a radiation generation source operable to emit radiation into a formation surrounding the tool, a radiation detector fixed relative to the radiation generation source and operable to detect backscattered radiation from the formation surrounding the tool, and a sleeve positioned around the radiation detector to shield the radiation detector from a first portion of the backscattered radiation. The sleeve includes at least one aperture for exposing the radiation detector to a second portion of the backscattered radiation, in which the second portion of the backscattered radiation emanates from an inspected region of the formation facing the at least one aperture. A signal measured at the radiation detector corresponds to the inspected region of the formation, and the position of the at least one aperture is changeable with respect to the formation to distinctly inspect different regions of the formation.

Abstract: A method for searching for and detecting gamma radiation sources in conditions of nonuniform radioactive contamination is provided. Stages in which a source of maximally active radiation is determined, the radiation power is measured with a collimated detector and at the same time the distance to the source is determined with the aid of a laser detector rangefinder. Readings of the laser rangefinder and the value of a dose rate are established by the detector are recorded. The dose rate of the radiation of the actual source is calculated, after which, to verify the distance measured to the radiation source, the aiming axis of the rangefinder is moved for a distance horizontally. The measurement is repeated and the distance recorded. The results of successive measurements of the distance are compared. If there is a divergence in the measurements within the laser rangefinder error limits, the information is acknowledged as reliable.

Abstract: The use of an environmental sensing wireline standoff may improve operations during borehole logging procedures. An environmental sensing wireline standoff may comprise a lower body, an upper body, and a cable insert. The cable insert may further comprise a first segment and a second segment, wherein the cable insert is disposed between the lower body and the upper body, and wherein the cable insert is configurable to clamp directly onto a wireline cable. The environmental sensing wireline standoff may further comprise a sensor package. A method of assembling an environmental sensing wireline standoff may comprise securing a first segment of a cable insert into a lower body, securing a second segment of the cable insert into an upper body, attaching the sensor package to the upper body, and securing the lower body to the upper body.

Abstract: A downhole tool to make one or more downhole measurements of laser-induced vaporization and/or pyrolysis of hydrocarbons is provided and disposed at a desired location within a wellbore. A tool head of the downhole tool is brought into sealing engagement with the wellbore wall. The fluid within an interior region enclosed by the tool head and the wellbore wall is evacuated and a measurement spot is irradiated with a laser to generate volatile hydrocarbons and/or pyrolytic hydrocarbons. Measurements are made on the volatile hydrocarbons and/or pyrolytic hydrocarbons and one or more formation properties are inferred based on the measurements. A low level of laser radiation intensity, irradiating some or all of the wellbore wall enclosing the interior region, may be used to prevent measurement contamination, and both medium power and high power levels of laser radiation may be used to first vaporize and then pyrolyze the hydrocarbons.

Abstract: A downhole tool operable for conveyance within a wellbore extending into a subterranean formation, and for obtaining one or more measurements of the subterranean formation, wherein the downhole tool comprises a sensor, a pressure housing containing the sensor and mounted on an external surface of the downhole tool, and a sliding stabilizer covering the pressure housing.

Abstract: Estimating a parameter of interest, comprising intermittently generating a calibration radiation source in the carrier, the calibration radiation source comprising a radioisotope producing radiation to which the radiation sensor is exposed. Methods include measuring a calibration response from the radiation sensor with measurement circuitry during the exposure to produce calibration information, and measuring another response from the radiation sensor with the measurement circuitry to produce measurement information after the radioisotope has decayed to a reduced radiation level such that the measurement information is substantially unaffected by the radioisotope. The radioisotope may be a positron emitter producing radiation by annihilation of the positrons emitted from the radioisotope. The radiation produced may thus be gamma rays.

Abstract: A downhole assembly includes a drill collar, the drill collar having an outer wall and an insert, the insert positioned within drill collar. The insert has a bore therethrough. The downhole assembly further includes at least one sensor within the insert, wherein the sensor is a gamma ray detector.

Abstract: A downhole ultrasonic transducer (10) used to transmit and/or receive ultrasonic waves in a hydrocarbon well where a fluid is present comprises: a metal housing (11) defining an internal cavity (12) isolated from the fluid of the hydrocarbon well (100) by a membrane wall (13) made of metal or metal alloy; a piezoelectric element (14) mounted inside the internal cavity (12), the piezoelectric element (14) having a front side (20) mechanically coupled on the membrane wall (13); wherein: the internal cavity (12) is at a pressure unrelated to a hydrocarbon well pressure; a back side (21) of the piezoelectric element (14) is arranged to be free to oscillate in the internal cavity (12) so as to generate a high acoustic impedance mismatch between the piezoelectric element (14) and the internal cavity (12) at the back side (21) and to maximize acoustic transmission at the front side (20); and a thickness (ei) of the membrane wall (13) is such that there is a common resonance between the membrane wall and the piezo

Abstract: An apparatus for inspecting integrity of a multi-barrier wellbore is described. The apparatus includes at least one source to generate radiation to impinge a target volume of the wellbore. The apparatus includes a source collimator having a plurality of alternating blocking channels and passing channels to direct radiation to impinge the target volume, such that the radiation directed from each passing channel forms a plurality of field of views extending radially into the target volume. The apparatus further includes at least one detector to receive backscatter rays arising from each respective field of view from the plurality of field of views and to generate an image representative of an inspected portion of the wellbore. The apparatus is useful for inspecting very small volumes in the multiple barriers of the wellbore and determine the integrity of the wellbore based on the different densities in the image of the inspected portion.

Abstract: A borehole fluid imaging system includes a plurality of radiation sources located circumferentially around the borehole. A plurality of radiation detectors are located circumferentially around the borehole. The plurality of radiation detectors detect the radiation transmitted by each of the respective ones of the plurality of radiation sources. A controller is coupled to the plurality of radiation detectors to determine an attenuation of the radiation at the plurality of detectors and generate an image of the fluid in response to the attenuation of the radiation.

Abstract: An apparatus for estimating a first property in a borehole penetrating the earth is described. The apparatus includes a carrier configured to be conveyed through the borehole. The apparatus also includes a first sensor disposed at the carrier and configured to perform a first measurement of the first property, the first sensor having a first direction of sensitivity; a second sensor disposed at the carrier and configured to perform a second measurement of a second property, the second sensor having a second direction of sensitivity; and a processor configured to receive the first and second measurements and to correct the first measurement using the second measurement in order to estimate the first property.

Abstract: Devices and methods for a rugged semiconductor radiation detector are provided. The semiconductor detector may include a hermetically sealed housing and a semiconductor disposed within the housing that has a first surface and a second surface opposite one another. A first metallization layer may at least partially cover the first surface of the semiconductor and a second metallization layer may at least partially cover the second surface of the semiconductor. The first metallization layer or the second metallization layer, or both, do not extend completely to an edge of the semiconductor, thereby providing a nonconductive buffer zone. This reduces electrical field stresses that occur when a voltage potential is applied between the first metallization layer and the second metallization layer and reduces a likelihood of electrical failure (e.g., due to arcing).

Abstract: A method for real-time analysis of results from a load test performed on a target website includes calculating first-level aggregated test results within each of a plurality of load server instances that generate a load on the target website. The first-level aggregated test results are calculated from data points received by each of the load server instances from the target website. The first-level aggregated test results include a sum of the data points, a count of the number of the data points, a sum of squares of the data points, and an average of the data points. A standard deviation result (STDEV) is calculated and chart is generated on a display via a graphical user interface. The chart provides a visual representation of a performance metric for the load test based on the standard deviation result.

Abstract: A method for determining a petrophysical property of a formation includes detecting radiation events resulting from imparting neutrons into the formation at an energy level of at least 1 MeV. The petrophysical property is determined from an elastic scattering cross section of the formation. The elastic scattering cross section is related to a number of detected radiation events.

Abstract: A downhole tool includes a tool body having an outer surface portion and an inner surface portion and a recess formed in one of the outer surface portion and inner surface portion. At least one removable electronic component access member is detachably mounted to the tool body. The removable electronic component access member provides access to electronic components housed in the recess. A metallic seal is provided on at least one of the tool body and the removable electronic component access member. The metallic seal prevents fluid ingress into the recess through the at least one removable electronic component access member.

Abstract: A method for determining mineralogy of a formation includes determining a model of arenites in the formation by performing a first type of linear regression on a plurality of elemental dry weights of the formation based upon a sum of elemental dry weights of calcium and magnesium being at least a given value, or performing a second type of linear regression on the elemental dry weights based upon the sum of the elemental dry weights of elemental calcium and magnesium being less than the given value. A model of arkoses in the formation is determined by performing a third type of linear regression on the elemental dry weights. A partitioning function is then determined. The mineralogy of the formation is then determined by applying the partitioning function to the model of arenites and the model of arkoses, and adding the model of arenites and the model of arkoses together.

Abstract: A tool for communicating data between multiple locations downhole includes a tool body, a first antenna including at least one electrode disposed within a wall and electrically insulated from the tool body, and an electronic circuit configured to generate an encoded electrical signal and propagate the encoded signal through the electrode into a medium surrounding the tool, and a second antenna coupled to the tool body, and an electronic circuit configured to receive an electrical signal induced by the second antenna.

Abstract: A method for analyzing a formation includes entering into a computer a number of detected gamma rays resulting from imparting neutrons into the formation. The detected gamma rays are characterized by energy levels thereof. A number of detected gamma rays in each energy level comprises a measured spectrum. In the computer, a non-Gaussian filter is applied to a reference spectrum to match the measured spectrum in shape. The filtered reference spectrum and measured spectrum are used to determine a fractional volume of at least one component of the formation.

Abstract: The invention relates to a wellbore-lining tubing comprising at least one window pre-formed in the wall of the tubing and a device for selectively generating a fluid pressure pulse, and to a method of forming a lateral wellbore employing such a tubing. In an embodiment, a wellbore-lining tubing (130m) is disclosed which comprises: a tubing wall (32m), an internal fluid flow passage (30m), and at least one window (154m) pre-formed in the wall of the tubing; a device (34m) for selectively generating a fluid pressure pulse, the device located at least partly in a space (36m) provided in the wall of the tubing; and a coupling (190) for receiving a deflection tool (192) so that the deflection tool can be secured to the tubing and employed to divert a downhole component (202) through the window in the tubing wall.

Abstract: Methods and related systems are described for gamma-ray detection. A gamma-ray detector is made depending on its properties and how those properties are affected by the data analysis. Desirable properties for a downhole detector include; high temperature operation, reliable/robust packaging, good resolution, high countrate capability, high density, high Z, low radioactive background, low neutron cross-section, high light output, single decay time, efficiency, linearity, size availability, etc. Since no single detector has the optimum of all these properties, a downhole tool design preferably picks the best combination of these in existing detectors, which will optimize the performance of the measurement in the required environment and live with the remaining non-optimum properties.

Abstract: Method for determining the density (D) of a multiphase fluid (F) flowing through a pipe (1) and containing a gas (G) which determines a fluctuation of the actual instantaneous density of the fluid (F), said method comprising the following steps: defining a series of consecutive time periods (S0, S) which are shorter than the time length corresponding to the highest frequency-component of the fluctuation of the actual instantaneous density; conveying through a section (2) of the pipe (1) a photon beam (3) suited to undergo an attenuation while crossing the fluid (F); counting the actual number (A) of photons of the beam (3) which cross the pipe (1) during a first time period (S) of the series; calculating a corrected count (C) as the weighted average value of the actual count (A) and of the corrected count (C0) calculated for the preceding time period (S0); converting the value of the corrected count (C) into a corresponding value of the density (D) of the multiphase fluid (F) for the first time period (S) thr

Abstract: A downhole tool to make one or more downhole measurements of laser-induced vaporization and/or pyrolysis of hydrocarbons is provided and disposed at a desired location within a wellbore. A tool head of the downhole tool is brought into sealing engagement with the wellbore wall. The fluid within an interior region enclosed by the tool head and the wellbore wall is evacuated and a measurement spot is irradiated with a laser to generate volatile hydrocarbons and/or pyrolytic hydrocarbons. Measurements are made on the volatile hydrocarbons and/or pyrolytic hydrocarbons and one or more formation properties are inferred based on the measurements. A low level of laser radiation intensity, irradiating some or all of the wellbore wall enclosing the interior region, may be used to prevent measurement contamination, and both medium power and high power levels of laser radiation may be used to first vaporize and then pyrolyze the hydrocarbons.

Abstract: A downhole tool for use in coiled tubing well operations. The tool includes a gamma ray detector for determining well location information for an associated coiled tubing application. The well location information may relate to well depth and/or the locating and identifying of a particular side branch or lateral leg of the well. Additionally, the gamma ray detector may be utilized to monitor dynamic well conditions in real-time such as the flow of injected fluids or the effectiveness of clean out applications via the coiled tubing.

Abstract: A method for identifying the type of a sampled formation fluid, such as a hydrocarbon, is provided. In one embodiment, the method includes measuring absorbance by a sample of a formation fluid at multiple wavelengths of electromagnetic radiation with a spectrometer. The method also includes distinguishing between multiple fluid types to identify a fluid type of the sample most likely to match an actual fluid type of the sample based on the measured absorbance at two or more wavelengths of the multiple wavelengths. Additional systems, devices, and methods are also disclosed.

Abstract: A connector system for reducing particulate matter may include a first unit for supplying signals and a second unit for receiving and/or relaying the signals. The signals may be for power generation and/or communications. A coupling may be positioned between the first unit and second unit. The coupling may include a center pin attached to the first unit and for receiving a signal at a first potential. The coupling may further include an outer case attached to the first unit and for receiving a signal at a second potential. The coupling may also have a seal and a spring. The seal and spring may surround the outer case. The spring may engage the second unit and may pass signals between the first unit and the second unit. The spring may comprise a canted coil spring for supporting load forces and for passing electrical current.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to acquire borehole standoff data (321), segregate the standoff data into a plurality of azimuthal bins (363), derive a plurality of diameters from the standoff data in the bins, determine an average borehole diameter from the plurality of diameters (367), calculate a standard deviation from the average borehole diameter (375), and compute a caliper measurement (383), a major elliptical axis length, and a minor elliptical axis length based on the average borehole diameter and the standard deviation (387).

Abstract: A drilling rig with bidirectional dual eccentric reamer which forms a larger wellbore than originally drilled and larger than the drill bit diameter. The bidirectional dual eccentric reamer has a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation which allows for the formation of a larger wellbore than originally drilled and larger than the drill bit diameter.

Abstract: A process analyzes gases emitted during drilling of a borehole using oil based mud. The process comprises (a) using mass spectrometry, analyzing the gas recovered during drilling through a hydrocarbon-poor zone at spaced apart locations to provide a mass spectrum for the gas emitted at each of the locations; (b) using mass spectrometry, analyzing the gas recovered during drilling through a hydrocarbon-rich zone at one location to provide a mass spectrum for the gas emitted at the location; (c) using spectra from the measurements in (a) to extrapolate and predict a peak in a mass spectrum caused by compounds in the mud at a time when the drilling is proceeding through the hydrocarbon-rich zone; and (d) comparing the spectrum obtained in (b) with the predicted spectrum obtained in (c) to further predict at least one of the quantity and identity of the formation gases emitted from the hydrocarbon-rich zone.

Abstract: In an embodiment, scintillator can have a Figure of Merit of 0.4 at a temperature greater than 120° C., a Figure of Merit of at least 0.05 at a temperature of at least 160° C., or both. In another embodiment, a scintillator can include a Br-containing or an I-containing elpasolite. Either scintillator can be used in a radiation detection apparatus that include a photosensor and a radiation detection apparatus. Such an apparatus can be used to detect and discriminate two different types of radiation over a wide range of temperatures. The radiation detection apparatus can be useful in drilling, well logging, or as a portal detector.

Abstract: A neutron logging tool has multiple detectors spaced about the circumference of the tool. The detectors are shielded from each other such that each detector detects gamma rays from the area of the borehole and formation to which it is closest. The log readings from each detector can be associated with the orientation of that detector. The orientation-specific log readings can then be aggregated to form an azimuthal log which can be used to analyze pre-fractured and/or post-fractured formations.

Abstract: A logging while drilling (LWD) tool can include a shock mounted sensor package with thermal isolation. For example, a LWD tool can include a pressure housing surrounding a cavity. A sensor package that includes at least one end connection can be coupled within the cavity. The LWD tool can also include a support structure coupled to the pressure housing and supporting the end connection of the sensor package. The support structure is configured to provide damping along at least one of the axial, radial, and azimuthal axes. The end connection is configured to inhibit thermal conductivity between the support structure and the sensor package.

Abstract: A downhole measurement apparatus includes a tool body supporting a logging tool. The logging tool includes a detector outsert coupled into and exposed through an exterior pocket of the tool body to position the outer surface of the outsert adjacent or in close proximity to the outer diameter of the tool body. A stabilizer or off-center stabilizer may be provided to further deflect the outsert portion of the logging tool toward an earth formation to increase detector proximity to the formation. The axial distance between the detector and a nuclear source can be calibrated using configurations of the nuclear source holder and the outsert. Retention mechanisms for the source holder and the outsert further enhance proximity and calibration.

Abstract: A system and method for use in a downhole tool having a fluid density measurement device positioned therein are provided. In one example, the method includes deploying the downhole tool at a first station in a borehole. The downhole tool is moved from the first station to a second station in the borehole. A plurality of fluid density values of fluid within the borehole between the first and second stations are measured using the fluid density measurement device in the downhole tool. The plurality of fluid density values may represent a continuous log of fluid densities between the first and second stations.

Abstract: Methods and apparatus for obtaining a mass spectrum of a sample and determining a concentration of a component of the sample by utilizing a model of chemical and electron ionization and the obtained mass spectrum.

Abstract: The present invention provides systems and methods capable of improving the efficiency and effectiveness of leaching operations. In one embodiment, the present invention may utilize a coiled tubing directional drilling system capable of treating interior portions of the heap/formation. In one embodiment, the present invention may utilize a system and method capable of capturing real time temperature and resistivity data pertaining to pregnant solution characteristics in the heap/formation. In one embodiment, the present invention may utilize one or more wire line deployed X-Ray Fluorescence (XRF) spectrometers capable of quantitatively measuring concentrations of desired metals in the heap/formation during leaching operations. In one embodiment, the present invention utilizes multiple passes of elemental capture spectroscopy logs acquired at regular time intervals to monitor metal concentrations during leaching operations.

Abstract: Disclosed are systems and methods for monitoring drilling fluid components in real time. One system includes a flow path fluidly coupled to a borehole and containing a drilling fluid having at least one component present therein, an optical computing device arranged in the flow path and having at least one integrated computational element configured to optically interact with the drilling fluid and thereby generate optically interacted light, and at least one detector arranged to receive the optically interacted light and generate an output signal corresponding to a characteristic of the at least one component.

Abstract: Logging-while-drilling tools incorporating an electronic radiation generator, such as an electronic X-ray generator, and a method for using the same are provided. One example of such a logging-while-drilling tool may include a circumferential drill collar, a chassis disposed radially interior to the drill collar, and an electronic X-ray generator and an X-ray detector disposed within the chassis. The electronic X-ray generator may emit X-rays out of the logging-while-drilling tool into a subterranean formation. The X-ray detector may detect X-rays that return to the logging-while-drilling tool after scattering in the subterranean formation, which may be used to determine a density and/or a lithology of the subterranean formation.

Abstract: A through casing formation evaluation tool string 1000, 2000, 3000 including a conveyance string 100, a sonic array tool 200, a pulsed neutron tool 400 and one or more downhole memory modules 160, 540, 550. A method of through casing formation evaluation and casing and cementing integrity evaluation includes lowering a tool string into a cased wellbore; concurrently collecting data with the sonic array tool and pulsed neutron tool and transmitting at least a portion of the collected data via a conveyance string to a CPU located at the surface of the earth; storing a portion of the collected data in a memory module disposed in the tool string; removing the tool string from the wellbore; processing the collected data in the CPU to obtain selected rock property data about the one or more of the geologic formations and/or cement integrity.

Abstract: The present disclosure relates to determining the attenuation of an electromagnetic signal passing through a conductive material. An antenna is provided and placed in relatively close proximity to the conductive material. An alternating current is passed through the antenna and the impedance of the antenna is measured. The attenuation is determined using the measured impedance. A single frequency measurement may be made, or multiple measurements using different frequencies may be made. Grouped parameters based on properties of the material and the frequency of the current are used to relate the coil impedance to the attenuation. A current frequency for which the ratio of the antenna's resistive part of the impedance to the angular frequency of the current is substantially insensitive to at least one of the parameters is preferred.

Abstract: A process analyses gases emitted during drilling of a borehole using oil based mud. The process comprises (a) using mass spectrometry, analysing the gas recovered during drilling through a hydrocarbon-poor zone at spaced apart locations to provide a mass spectrum for the gas emitted at each of the locations; (b) using mass spectrometry, analysing the gas recovered during drilling through a hydrocarbon-rich zone at one location to provide a mass spectrum for the gas emitted at the location; (c) using spectra from the measurements in (a) to extrapolate and predict a peak in a mass spectrum caused by compounds in the mud at a time when the drilling is proceeding through the hydrocarbon-rich zone; and (d) comparing the spectrum obtained in (b) with the predicted spectrum obtained in (c) to further predict at least one of the quantity and identity of the formation gases emitted from the hydrocarbon-rich zone.

Abstract: A portable analytical system for the rapid on-site analysis of fluids, and a method for using this system at the well-site for the analysis of samples extracted from drilling fluids is described. The portable analytical solution may be deployed at the well-site and used to perform detailed real-time analysis of formation fluids and extracts of rock cuttings. The method described could be used during hydrocarbon exploration and production to determine whether the drill stem has passed through a hydrocarbon-bearing region, or rocks that are capable of functioning as an oil reservoir or that may have been a source rock, or that may have come into contact with oil, or that may contain oil at present.