Abstract: In some embodiments, an apparatus [100] and a system, as well as a method and an article, may operate to transmit downhole data in a drilling fluid via fluid pressure modulation, and receive the downhole data at a fluid pulse receiver included in a conduit [104] coupled to a drill pipe downstream from a Kelly hose. Other apparatus, systems, and methods are disclosed.

Abstract: A method for communicating data in an offshore data communication system comprises measuring L/MWD data with a sensor disposed in a bottomhole assembly positioned in a subsea borehole. The bottomhole assembly is disposed along a drillstring extending through the subsea borehole. In addition, the method comprises communicating the L/MWD data from the bottomhole assembly to the seafloor with a telemetry signal. Further, the method comprises receiving the telemetry signal with at least one telemetry transducer positioned proximal the sea floor. Still further, the method comprises processing the telemetry signal at the seafloor to produce a processed signal. Moreover, the method comprises transmitting the processed signal from the sea floor to the sea surface.

Abstract: An apparatus to detect a pressure signal in a fluid flowing in a conduit comprises a flexible band sized to fit at least partially around the conduit. An optical fiber is flexibly adhered to the flexible band. At least one fastener is attached to the flexible band to fasten the flexible band at least partially around the conduit. A method for detecting a pressure signal in a conduit comprises adhering an optical fiber to a flexible band. At least one fastener is attached to the band. The band is fastened around the conduit such that a strain induced in the conduit by the pressure signal is transmitted to the optical fiber.

Abstract: An apparatus for detecting data in a fluid pressure signal in a conduit comprises an optical fiber loop comprises a measurement section and a delay section wherein the measurement section is disposed substantially circumferentially around at least a portion of the conduit, and wherein the measurement section changes length in response to the fluid pressure signal in the conduit. A light source injects a first optical signal in a first direction into the measurement section and a second optical signal in a second direction opposite the first direction into the delay section. An optical detector senses an interference phase shift between the first optical signal and the second optical signal and outputs a first signal related thereto.

Abstract: An apparatus comprising an encoded pressure signal propagating in a fluid flowing in a conduit. An optical fiber measurement element has a reflector on one end and is disposed around at least a portion of the conduit. A light source injects a second optical signal and a third optical signal propagating in first and second optical fibers, respectively. A delay section is disposed in the second optical fiber. The second optical signal and the third optical signal are directed into the optical fiber measurement element and are reflected back from the reflective end such that at least a portion of the reflected second and third optical signals propagate through the second and first optical fibers respectively to an optical detector. The optical detector senses an interference between the reflected optical signals and outputs a first signal related thereto.

Abstract: A method and system for determining a property of a sample of fluid in a borehole. A fluid sample is collected in a downhole tool. While collecting, X-rays are transmitted proximate the fluid from an X-ray source in the tool and an X-ray flux that is a function of a property of the fluid is detected. The detected X-ray flux data is processed to determine the property of the fluid.

Abstract: Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor.

Abstract: In some embodiments, an apparatus [100] and a system, as well as a method and an article, may operate to transmit downhole data in a drilling fluid via fluid pressure modulation, and receive the downhole data at a fluid pulse receiver included in a conduit [104] coupled to a drill pipe downstream from a Kelly hose. Other apparatus, systems, and methods are disclosed.

Abstract: Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor.

Abstract: Methods and systems for controlling the drilling of a borehole are disclosed. The methods employ the assumption that nonlinear problems can be modeled using linear equations for a local region. Common filters can be used to determine the coefficients for the linear equation. Results from the calculations can be used to modify the drilling path for the borehole. Although the calculation/modification process can be done continuously, it is better to perform the process at discrete intervals along the borehole in order to maximize drilling efficiency.

Abstract: A method for measuring one or more characteristics of an earth formation wherebyenergy is emitted circumferentially about a borehole into the formation, and the amount reflected back is detected during a plurality of sample periods. The samples are grouped into two or more groups by the azimuthal sector in which the sample was collected. Within a group, each sample is mathematically weighted according to the standoff of the detector from the borehole wall when the sample was taken. Within a group, the weighted samples are summed to produce a weighted total amount of energy detected within a sector. The weighted total is then transformed into the one or more characteristics.

Abstract: A method for measuring one or more characteristics of an earth formation whereby energy is emitted circumferentially about a borehole into the formation, and the amount reflected back is detected during a plurality of sample periods. The samples are grouped into two or more groups by the azimuthal sector in which the sample was collected. Within a group, each sample is mathematically weighted according to the standoff of the detector from the borehole wall when the sample was taken. Within a group, the weighted samples are summed to produce a weighted total amount of energy detected within a sector. The weighted total is then transformed into the one or more characteristics.

Abstract: A method for measuring one or more characteristics of an earth formation whereby energy is emitted circumferentially about a borehole into the formation, and the amount reflected back is detected during a plurality of sample periods. The samples are grouped into two or more groups by the azimuthal sector in which the sample was collected. Within a group, each sample is mathematically weighted according to the standoff of the detector from the borehole wall when the sample was taken. Within a group, the weighted samples are summed to produce a weighted total amount of energy detected within a sector. The weighted total is then transformed into the one or more characteristics.

Abstract: A method and apparatus for determining at least one characteristic of a formation is provided which includes storing a plurality of counts received from both a long space radiation detector and a short space radiation detector. The counts are detected during a plurality of short duration time periods which are brief compared to rotary drilling speed. A count rate mean is determined and used to sort each of the plurality of count measurements into one of at least three bins. Count information accumulated in at least one of the bins is used to calculate a corrected density. A short space collimator enhances the count rate of singly scattered gamma rays detected by the short space detector and blocks gamma rays from the formation radially outwardly of the short space detector to improve spine-rib correction characteristics for relatively short standoffs. The method of sorting the plurality of short duration time period measurements improves the accuracy for short standoffs to larger standoffs.