Abstract: Sensor-enabled cutting elements for an earth-boring drilling tool may comprise a substrate base, and a cutting tip at an end of the substrate base. The cutting tip may comprise a tapered surface extending from the substrate base and tapering to an apex of the cutting tip, and a sensor coupled with the cutting tip. The sensor may be configured to obtain data relating to at least one parameter related to at least one of a drilling condition, a wellbore condition, a formation condition, and a condition of the earth-boring drilling tool. The sensor-enabled cutting elements may be included on at least one of an earth-boring drill bit, a drilling tool, a bottom-hole assembly, and a drill string.

Abstract: A temperature sensing arrangement includes a member having a first coefficient of thermal expansion, and an optical fiber having a second coefficient of thermal expansion. The optical fiber is strain transmissively mounted to the member. And the second coefficient of thermal expansion is greater than the first coefficient of thermal expansion such that strain measurable in the optical fiber is correlatable to temperature changes in the member.

Abstract: A communication method includes: receiving input data at a transmitter, the transmitter including at least one convolutional encoder and at least one modulator; applying the input data to a trellis-coded modulation (TCM) scheme to encode the input data and produce one or more TCM symbols representing the encoded data; applying the one or more TCM symbols to a second modulation scheme, the second modulation scheme including a pulse modulation in combination with an additional modulation; and generating one or more modulation symbols representing the encoded data based on the second modulation scheme.

Abstract: A method for estimating a property of an earth formation penetrated by a borehole includes: performing a borehole integrity test at a pressure less than a fracture gradient pressure of the formation to provide leakage data; injecting a fluid into the formation at a first pressure greater than the fracture gradient pressure during a first injection time interval using a fluid injector; measuring pressure versus time using a pressure sensor and a timer during a first test time interval to provide first pressure data; injecting a fluid into the formation at a second flow rate greater than the first flow rate during a second injection time interval using the fluid injector; measuring pressure versus time using the pressure sensor and the timer during a second test time interval to provide second pressure data; and estimating the property using the first pressure data, the second pressure data, and the leakage data.

Abstract: A system for logging with wired drill pipe includes a logging tool string; an interface sub in operable communication with the logging tool string; and a wired pipe in operable communication with the interface sub and method for logging with wired drill pipe.

Abstract: A sampling tool for retrieving one or more samples from a wellbore drilled in a subterranean formation includes a coring device retrieving a core from a wellbore wall, wellbore isolation devices that isolate an annular region proximate to the coring device; and a flow device that flows fluid out of the isolated region. During operation, the sampling tool is positioned adjacent a formation of interest. The isolation device is activated to isolate an annular region proximate to the sampling tool. Decentralizing arms can be used to position the coring device next to the wellbore wall. Thereafter, the flow device flows fluid out of the isolated annular region. When the isolated region includes mostly formation fluid, the coring device is activated to retrieve a core from a wall of the wellbore in the isolated annular region and store it in formation fluid.

Abstract: Disclosed herein relates to a single piece tubular member. The tubular member having a non-radially displaceable portion and a radially displaceable portion, the radially displaceable portion being movable to a position of similar radial displacement as that of the non-radially displaceable portion and a position of relatively large radial displacement in comparison to the non-radially displaceable portion. The tubular member also having at least one cutting arrangement disposed at the radially displaceable portion.

Abstract: Disclosed herein relates to a single piece tubular member. The tubular member having a non-radially displaceable portion and a radially displaceable portion, the radially displaceable portion being movable to a position of similar radial displacement as that of the non-radially displaceable portion and a position of relatively large radial displacement in comparison to the non-radially displaceable portion. The tubular member also having at least one cutting arrangement disposed at the radially displaceable portion.

Abstract: A solid lubricant is added to the internal passages of an air cooled bit such that the air erodes, or ablates, the solid lubricant into the air stream. Compressed air travels down the drill stem to the bit. The air passes through an air tube into the main air passage where the solid lubricant has been placed. As the air passes the solid lubricant, it erodes the solid lubricant. The solid lubricant particles ablated into the air stream travel through the ball passage into the journal air passage and out to the bearing surfaces between the cutter and the journal. The air stream both cools the surfaces and deposits the solid lubricant to reduce the friction between the bearing surfaces.

Abstract: The present invention provides a method for forming wellbores. In one method, one or more wellbores are drilled along preplanned paths based in part upon seismic surveys performed from the surface. An acoustic transmitter conveyed in such wellbores transmits acoustic signals at a one or more frequencies within a range of frequencies at a plurality of spaced locations. A plurality of substantially serially spaced receivers in the wellbores and/or at surface receive signals reflected by the subsurface formations. The sensors may be permanently installed in the boreholes and could be fiber optic devices. The receiver signals are processed by conventional geophysical processing methods to obtain information about the subsurface formations. This information is utilized to update any prior seismographs to obtain higher resolution seismographs. The improved seismographs are then used to determine the profiles of the production wellbores to be drilled.

Abstract: A method and apparatus for nuclear logging, and in particular, neutron porosity logging is presented. In accordance with the present invention, a pair of spaced lithium detectors, preferably Li.sup.6 I crystal or Li.sup.6 doped glass are used to detect neutrons emitted from a borehole formation being logged. In addition, novel data processing is used to determine the neutron count from the spectrum developed by the lithium detectors. This novel data processing comprises fitting a Gaussian curve to the neutron peak of the spectrum. The Gaussian curve does not include the hydrogen absorption peak of the spectrum. The area under this Gaussian curve represents the neutron count. Accordingly, a more accurate neutron count is obtained which does not include gamma rays attributed to hydrogen absorption.