Schlumberger Technology Corporation

Clarapath, Inc.

Geoservices Equipements

Gwr Instruments, Inc.

Schlumberger-doll Research

Prad Research and Development Nv

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Robert L Kleinberg

Douglas D Griffin, Ii

Abdurrahman Sezginer

Weng C Chew

Brian Oliver Clark

Charles Flaum

Masafumi Fukuhara

Neil William Bostrom

Kenneth Edward Stephenson

Ravinath Kausik Kadayam Viswanathan

Andrew Emil Pomerantz

Martin D Hurlimann

Gary Martin Oddie

Partha Pratim Mitra

Anthony Robert Holmes Goodwin

Austin Boyd

Paul Ryan Craddock

Robert Allen Badry

David P Madio

David R Mariani

Alexander S Tolpygo

Oliver Clinton Mullins

Peter Speier

Robert Freedman

Lalitha Venkataramanan

Krishnamurthy Ganesan

Anthony R H Goodwin

Shu-Kong Chang

Jagdish H Shah

Richard E Lewis

Nikita Valentinovich Seleznev

Shawn David Taylor

Anthony Goodwin

William E Kenyon

Shigeo Daito

Lukasz Zielinski

Frank Shray

Steven F Crary

Mark Flaum

Christian Straley

Richard W Gaylor

Nadege Bize-Forest

Richard J Warburton

Edward Y Chow

Olivier Faivre

Stacy Lynn Reeder Blanco

Stacy L Reeder

Jakob Bu Haldorsen

Rodolfo Oliveira

Victoria Baines

Andre Bertolini

Peter G Brewer

Abdurranhman Sezginer

Peter I Day

Max Lipsicas

Lawrence L Latour

Martin Erich Poitzsch

Donald G Dudley

Flavio Da Costa Ferreira

Neil W Bostrom

Robert Badry

Shawn Taylor

A system and method for automated transfer of a tape segment onto the face of a tissue block to be thin sectioned by microtomy includes applying, to a carrier strip, a plurality of serially-spaced patches of sample tape having an adhesive outer surface, transporting the carrier strip along a path adjacent to and spaced from the exposed sample surface to position one of the patches of sample tape adjacent to and covering the exposed sample surface, adhering the one of the patches of sample tape to the exposed sample surface.

Method, system, and device for automating transfer of tape to microtome sections

Irreducible water saturation of fluid-storing porous reservoir rock is determined using methods that include obtaining a reservoir rock sample from the underground fluid reservoir; performing mercury saturation measurements on the reservoir rock sample for different mercury injection pressure values to obtain mercury saturation values for the different mercury injection pressure values; and estimating the irreducible water saturation (Sw) from the mercury saturation values and the mercury injection pressure values by correcting for surface films of fluid retained on pore walls of the reservoir rock.

Method for estimating irreducible water saturation from mercury injection capillary pressure

Levels of kerogen and bitumen are computed in a sample of rock from DRIFTS measurements on the sample. The DRIFTS spectrum of a rock sample is measured, resulting in an estimate of bitumen and kerogen. Bitumen is then washed from the rock and DRIFTS is re-measured, resulting in an estimate of kerogen. Bitumen quantity is calculated by subtracting the washed sampled results from first DRIFTS measurements.

Bitumen quantification using vibrational spectroscopy

Techniques for calculating metrics for reservoir quality based on light oil and total organic carbon in tight oil reservoirs are described. The techniques include calculating quantities of light oil and total organic carbon from logging data and generating therefrom a continuous log for reservoir quality metric. Additionally new reservoir quality indices are presented that more accurately predict reservoir quality in tight oil plays.

Quality metrics for tight oil reservoirs

An exploration paradigm for detecting and/or characterizing gas hydrate deposits using either electromagnetic or seismic surveys, that accounts for the possibility that gas hydrate may accumulate in vertical or subvertical dikes. Geologic factors, such as the presence of the gas hydrate stability zone, indications that a prolific source of gas exists (or existed) below the gas hydrate stability zone and indications that a high flux of gas could be transported into the gas hydrate stability zone, may be considered as part of an exploration strategy. Data may be collected using seismic techniques, such as a walk-away vertical seismic profile techniques, or electromagnetic surveys that are adapted to detecting the presence of vertical or subvertical dikes. In one example, data processing and acquisition techniques may be adapted to detect hydrate dikes, and do not assume a horizontally isotropic earth model.

Method and apparatus for locating gas hydrate

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.

Electrical heating of oil shale and heavy oil formations

Methods for the determination of the Total Gas in Place (TGiP) in gas-bearing formations are provided. Aspects of the subject disclosure also relate to the determination of the TGiP from nuclear magnetic resonance (NMR) logs alone or in combination other well logs.

Multiphysics NMR logging techniques for the determination of in situ total gas in gas reservoirs

Methods and apparatus for the characterization of formation fluids are disclosed. A downhole tool disposed in a borehole penetrating a subterranean formation obtains a NMR measurement, effects a change in a characteristic of the formation fluid, and obtains another NMR measurement subsequent to the change. Alternatively, the downhole tool effects a radial gradient of a characteristic of the formation and obtains NMR measurements at two or more selected radial distances from the wellbore wall. A parameter representative of the subterranean formation or the formation fluid is further determined from the NMR measurements.

Methods and apparatus for monitoring a property of a formation fluid

A heat switch for remote self-contained gas chromatography is disclosed. The device mechanically separates a hot or cold reservoir from the chromatography column when heating or cooling is not needed. The column needs a cooling system to obtain initial temperatures below ambient. At other times the column needs to be heated to relatively high temperatures, during which time the cooling system is preferably detached. The heat switch allows for rapid temperature changes while minimizing the peak cooling power requirement.

Heat switch for chromatographic system and method of operation

For use in logging downhole in an earth borehole, a method for determining a characteristic of oil, includes: providing and determining the viscosity of a plurality of crude oil samples; performing test measurements, using a predetermined operating mode, on media including the crude oil samples to obtain test data; applying a test processing procedure to the test data to obtain an output test parameter relating to the test data and the predetermined operating mode; deriving, for the plurality of crude oil samples, a correlation relating the output test parameter to the viscosities of the crude oil samples; performing downhole measurements in the measurement region with a logging device, operated with substantially the predetermined operating mode, to obtain logging data, and applying a measurement processing procedure to the logging data to obtain an output logging parameter; and determining the oil characteristic using the output logging parameter and the correlation.

Logging method for determining characteristic of fluid in a downhole measurement region

A self-contained chromatography system is provided and includes a chromatography column, a carrier gas reservoir containing a carrier gas and an analyte stream processing device, wherein the carrier gas reservoir is disposed upstream from the chromatography column and wherein the analyte stream processing device is disposed downstream from the chromatography column. A method for implementing the self-contained chromatography system is also provided and includes generating a first system pressure upstream from the chromatography column and a second system pressure downstream from the chromatography column to cause the carrier gas to flow between the carrier gas reservoir and the analyte stream processing device. The method further includes combining a sample material with the carrier gas, introducing the combined sample to the chromatography column to generate the analyte stream and processing the analyte stream via the analyte stream processing device.

Self-contained chromatography system

A control system for a hydrocarbon well is also disclosed. A control valve system is used to control the flow of fluid being produced by the well. A real time sensor is provided downhole and is used to make real time measurements of phase characteristics of the fluid. A controller is used to control the valve system so as to reduce the risk of undesirable phase transitions in the fluid based on the real time measurements made by the sensor. The sensor includes an acoustic transducer configured to emit acoustic energy into the fluid at a level which causes a phase transition in the fluid. The controller determines the level of acoustic energy emitted into the fluid, and also determines the pressure associated with a phase transition using the level of emitted acoustic energy.

Method and system of fluid analysis and control in hydrocarbon well

The present invention discloses a diffusion edited pulse technique that allows information about a fluid to be extracted, comprising: a) obtaining a fluid sample; b) generating a sequence of magnetic field pulses in the fluid, the sequence comprising an initial magnetic field pulse, a first portion that follows the initial magnetic field pulse, and a second portion that follows the first portion; c) detecting magnetic resonance signals using the second portion of the sequence; d) modifying the first portion of the sequence, and repeating steps (b) and (c); and e) extracting information about the fluid by determining relaxation and diffusion characteristics and their correlation based on the signals detected in steps (c) and (d). Also disclosed is a logging tool equipped with a processor to implement the diffusion edited pulse technique.

Nuclear magnetic resonance method and logging apparatus for fluid analysis

The present invention discloses a method and apparatus to make a nuclear magnetic resonance measurement on a flowing fluid using varied wait times. In one method, NMR measurements are made by: a) flowing the fluid through a static magnetic field; b) applying a group of oscillating magnetic field pulses to the flowing fluid, wherein the group of pulses is comprised of an initial pulse and one or more refocusing pulses; c) detecting magnetic resonance signals from the flowing fluid; d) after a wait time, repeating (b) and (c) one or more times, wherein at least two of the repetitions have varied wait times; and e) analyzing the detected magnetic resonance signals to extract information about the flowing fluid. Further, varied wait time measurements may be useful in determining the flow rate of the sample.

Nuclear magnetic resonance apparatus and methods for analyzing fluids extracted from earth formation

Growing community of inventors

Ridgefield, CT, United States of America

Robert L Kleinberg