Abstract: A method for making a well-logging tool for positioning in a wellbore of a geologic formation includes forming a radiation detector by securing a scintillator window and a scintillator housing together and joining together opposing ends of a photomultiplier housing and a scintillator housing. The method further includes securing the scintillator window to the scintillator housing with a brazed joint. The radiation detector is positioned within a well-logging housing.

Abstract: An ion source for use in a radiation generator includes an active cathode configured to emit electrons on a trajectory away from the active cathode, at least some of the electrons as they travel interacting with an ionizable gas to produce ions. In addition, there is at least one extractor downstream of the active cathode having a potential such that the ions are attracted toward the at least one extractor.

Abstract: An ion source for use in a radiation generator includes a sealed envelope containing an ionizable gas therein. The ion source also includes a RF antenna external to the sealed envelope, the RF antenna to transmit time-varying electromagnetic fields within the sealed envelope for producing ions from the ionizable gas. There is at least one extractor within the sealed envelope having a potential such that the ions are attracted toward the at least one extractor.

Abstract: A method (and system) is provided that enhances production of hydrocarbons from a subterranean formation by identifying at least one target interval of the subterranean formation that is in proximity to a pay interval, wherein the at least one target interval has an electrical resistance less than electrical resistance of the pay interval. A plurality of electrodes are placed in positions spaced apart from one another and adjacent the at least one target interval. Electrical current is injected into the target interval by supplying electrical signals to the plurality of electrodes. The electrical current injected into the at least one target interval passes through at least a portion of the at least one target interval in order to heat the at least one target interval and heat the pay interval by thermal conduction for enhancement of production of hydrocarbons from the pay interval.

Abstract: A method for treating a subterranean formation penetrated by a wellbore, comprising: providing a treatment slurry comprising a carrying fluid, a solid particulate and an agglomerant; injecting the treatment slurry into a fracture to form a substantially uniformly distributed mixture of the solid particulate and the agglomerant; and transforming the substantially uniform mixture into areas that are rich in solid particulate and areas that are substantially free of solid particulate, wherein the solid particulate and the agglomerant have substantially dissimilar velocities in the fracture and wherein said transforming results from said substantially dissimilar velocities is provided.

Abstract: A radiation detector is used in a well-logging tool for positioning in a wellbore of a geologic formation. The radiation detector includes a photomultiplier housing and a scintillator housing. A housing coupler joins together opposing ends of the photomultiplier housing and scintillator housing. A photomultiplier is contained within the photomultiplier housing and a scintillator body is contained within the scintillator housing. A scintillator window is secured to the housing coupler.

Abstract: A blending system for oilfield operations is disclosed having a first stage pump with a mixer having a housing and an impeller and configured to receive a liquid component at an initial pressure and a dry component and mix the liquid and dry components to form a slurry, add energy to the slurry to increase its pressure above the initial pressure, and discharge the slurry through an outlet at a first pressure, and a second stage pump with an inlet and an outlet, the inlet in fluid communication with the first stage pump. The second stage pump is configured to receive the slurry from the first stage pump and pressurize the slurry to a second pressure at the outlet of the second stage pump. The second stage pump is positioned relative to the first stage pump to minimize a pressure loss between the first stage pump and the second stage pump.

Abstract: A system includes a first fluid comprising a viscosified fluid composed to generate an initial fracture geometry, a first spacer fluid, a second fluid being a high solids content fluid (HSCF) having a fine particle formulation, a third fluid being an HSCF having a coarse particle formulation, a second spacer fluid, a conventional proppant slurry fluid, and a flush fluid. The system includes a positive displacement pump fluidly coupled to a wellbore, the wellbore intersecting a formation of interest, and a controller that executes functions to perform complex fracture generation in the formation of interest. The controller provides pump commands to deliver a number of stage groupings to the formation of interest, each stage grouping including the first fluid, the first spacer fluid, the second fluid, the third fluid, and the second spacer fluid.

Abstract: A radiation detector includes a housing to contain a radiation detecting gas. The housing has a first thermal expansion over an operating temperature range. An elongate electrode extends within the housing and has opposing first and second ends, with the first end secured to adjacent portion of the housing. The elongate electrode has second thermal expansion over the operating temperature range defining a difference with respect to the first thermal expansion. A temperature compensator is coupled between the second end of the elongate electrode and an adjacent portion of the housing. The temperature compensator has a third thermal expansion over the operating temperature range to maintain a tension on the elongate electrode within a desired range over the operating temperature range.

Abstract: Method and systems for determining bubble point pressure of a fluid sample are described herein. The method includes transmitting light through the fluid sample and detecting transmitted light. The method also includes applying a series of thermal pulses to the fluid sample. The series of thermal pulses includes a time interval between each thermal pulse. The pressure of the fluid sample is varied and the bubble point pressure of the fluid sample is determined using an intensity of the transmitted light that corresponds to a time interval between the thermal pulses.

Abstract: A method for geological formation analysis may include collecting time-lapsed well-based measurement data from a first borehole in a geological formation over a measurement time period, and collecting time-lapsed electromagnetic (EM) cross-well measurement data via a plurality of spaced-apart second boreholes in the geological formation over the measurement time period. The method may further include determining simulated changes to a hydrocarbon resource in the geological formation over the measurement time period based upon a geological model using a processor, and using the processor to determine if the simulated changes are within an error threshold of the time-lapsed well-based measurement data and the time-lapsed cross-well EM measurement data. If the simulated changes are not within the error threshold, then the geological model may be updated.

Abstract: Fluid analysis measurements may be performed during withdrawal of a downhole tool to the surface. Fluid may be collected within a fluid analysis system of the downhole tool and the collected fluid may be exposed to the wellbore pressure during withdrawal of the downhole tool. Measurements for the collected fluid, such as optical density, the gas oil ratio, fluid density, fluid viscosity, fluorescence, temperature, and pressure, among other, may be recorded continuously or at intervals as the downhole tool is brought to the surface. The measurements may be employed to determine properties of the collected fluid, such as the saturation pressure and the asphaltene onset pressure.

Abstract: A drill bit includes a plurality of blades. The blades provide a plurality of cutting elements or teeth arranged on a leading face of the blade. At least one temperature sensor is provided adjacent at least one of the teeth of at least one blade to sense a local temperature of the blade adjacent that tooth. Multiple temperature sensors may be provided adjacent different teeth of a blade or adjacent the teeth of at least two blades, or adjacent multiple teeth of multiple blades. Another temperature sensing element may be provided on a proximal portion of the blade distant from the cutting elements or on the shank of the bit to provide a reference temperature for the drill bit or for the blade. Information obtained by the temperature sensing elements is used to provide information regarding at least one of the drill bit, the drilling environment and the formation.

Abstract: Methods and apparatus for estimating borehole mud slownesses are disclosed. An example method includes estimating a borehole drilling fluid slowness value based on a tube wave modulus value, a tube-wave slowness value, and a drilling fluid density value. The borehole is associated with an anisotropic elastic medium.

Abstract: A system and methodology facilitates extending the reach of coiled tubing during a well operation. The technique employs tubing which is deployed along wellbore. A plurality of extended reach devices is positioned along the tubing. Each extended reach device has at least one internal guide member oriented for extension into an interior of the tubing. The guide member engages and guides the coiled tubing during movement of the coiled tubing along the interior of the tubing, thus enabling an extended reach during a wellbore servicing application.

Abstract: Downhole seismic receiver systems that may be compatible with measurement-while-drilling systems. The downhole seismic receiver systems may be integrated into drill-string components, including drill collars of a bottom hole assembly. The downhole seismic receiver systems include one or more receiver subsystems which in turn include at least two or more same-type seismic sensors. The downhole seismic receiver systems are compatible with low frequency seismic sources and may be useful in determining orientation and location of bed boundaries around a wellbore and ahead of a drill-bit. The downhole seismic receiver systems can be operated with a downhole or surface source. Methods for downhole seismic, including single well and cross-well seismic. The methods may include analyzing data acquired by the receiver systems to obtain seismic information around the wellbore and ahead of the drill bit.

Abstract: Downhole seismic sources that may be compatible measurement-while-drilling systems. The downhole seismic sources are integrated into drill string components, including drill collars of the bottom hole assembly. The downhole seismic sources may generate a low swept frequency signal suitable for imaging around the drill-string and ahead of the drill bit. Integrated downhole seismic systems including a downhole seismic source, receivers and optionally data processing capabilities. The integrated systems may be configured to determine the distance and orientation of bed boundaries, including ahead of the drill bit up to about 200 m to 500 m in depth. Methods for downhole seismic, including single well and cross-well seismic. The methods may include obtaining seismic information ahead of the drill bit.

Abstract: A method for directional drilling of a wellbore includes automatically rotating a drill string having a steerable drilling motor at an end thereof in a first direction so that a measured torque related parameter thereon reaches a first value. The drill string is automatically rotated in a second direction so that the measured torque related parameter reaches a second value lower than the first value. A rate of release of the drill string is automatically controlled so that at least one of selected drilling fluid pressure and a range thereof is maintained.

Abstract: A method for thermoelastic logging in a borehole of a subterranean formation. The method includes generating, by a computer processor, a reference dispersion based on a borehole wave dispersion measurement of the borehole, wherein the reference dispersion represents far-field elastic properties in the subterranean formation, analyzing, by the computer processor, a difference between the reference dispersion and the borehole wave dispersion measurement based on a thermoelastic model of the subterranean formation to generate an analysis result, and determining, by the computer processor and based on the analysis result, a temperature dependent parameter of the subterranean formation.

Abstract: A method, system, and computer readable medium is disclosed to estimate a survey parameter (e.g., attitude) for a drilling operation in a subterranean formation. The survey parameter is calculated using multiple methods with the results of the different methods weighted to improve the accuracy at a given attitude of the tool and angular velocity of the sensor package. Results from the different methods are combined based on a weighting function to generate the improved values of inclination and azimuth. Specifically, the values of the weighting function depend, linearly or non-linearly, on the attitude of the tool and quality of the survey data. In one scenario, the attitude of the tool is approximated by the most recently obtained static inclination/azimuth. In addition, the quality of the survey data is approximated by a measure of vibration severity that is represented by the number of good data points based on the roll rate.