Schlumberger Technology Corporation

Louisiana State University and Agricultural & Mechanical College

John J Ullo

Tsutomu Yamate

Anthony Frank Veneruso

Kazuhiko Matsumoto

Jiro Takeda

David Gerez

Bingqing Wei

Harold Sherman

Hidetoshi Yoshiuchi

Abhilash Krishna

Certain embodiments disclosed herein are directed to devices for cooling. In certain examples, a thermoelectric device comprising a substrate and a superlattice coupled to the substrate is disclosed. In some examples, the superlattice includes a first semi-conducting material and a second semi-conducting material coupled to the first semi-conducting material to provide an interface between the first and second semi-conducting materials.

Devices for cooling and power

Subterranean sensing devices configured or designed for downhole use to sense a local condition in the well. The sensing devices comprise one or more transistor having at least one carbon nanotube field effect transistor (CNT FET) configured or designed for operation downhole, within a borehole.

Downhole sensing system using carbon nanotube FET

A nano-based device includes a support structure providing a support surface, a second structure providing a second surface angled with respect to the support surface, and at least one nano-emitter provided on the second surface.

Nano-based device and method

Method and apparatus for distinguishing oil from fresh water in situ in a subsurface geological formation are proposed which utilize the anomalous response of a neutron porosity tool to some oils. Apparent porosity derived from a neutron porosity investigation tool which measures spatial neutron flux distribution is compared to the porosity derived from a second investigating tool whose response is not or at least is less sensitive to the hydrogen density of the formation fluid than is the neutron porosity tool. Where a real difference is evident, oil rather than fresh water is indicated.

Method and apparatus for distinguishing hydrocarbon from fresh water in

Method and apparatus for determining the hydrogen and carbon densities of oil in situ in a subsurface geological formation are proposed which utilize the response of a neutron porosity tool to some oils. Apparent porosity derived from a neutron porosity investigation tool, which measures spatial neutron flux distribution, is compared to the porosity derived from a second investigating tool whose response is not or at least is less sensitive, say, to the hydrogen density of the formation fluid than is the neutron porosity tool. The magnitude of the difference is indicative of the hydrogen and carbon densities of the oil.

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Bethel, CT, United States of America

John J Ullo