Schlumberger Technology Corporation

Total Sa

Schlumberger Technology Corpoation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Gary Martin Oddie

Ashley Bernard Johnson

Kenneth Edward Stephenson

Cheng-Gang Xie

Andrew Meredith

Paul Simon Hammond

Franck Bruno Jean Monmont

Terizhandur S Ramakrishnan

Michael John Williams

Herve Ohmer

Robert L Kleinberg

Nathan Scott Lawrence

Iain Michael Cooper

Douglas D Griffin, Ii

Anthony Robert Holmes Goodwin

Dominic Joseph Brady

Laurent Pirolli

Allan Peats

Sam Smonian

Oliver Clinton Mullins

Christian Stoller

Reza Taherian

Arthur H Hartog

Tsutomu Yamate

Li Jiang

Craig David Johnson

Christopher Harrison

Kentaro Indo

Bhavani Raghuraman

Gokturk Tunc

Stephane Vannuffelen

Murtaza Ziauddin

Chengli Dong

Songming Huang

Frank F Espinosa

Fadhel Rezgui

Spyro J Kotsonis

Albert Ballard Andrews

Akira Kamiya

Ian Atkinson

Paul Bolchover

Andrew John Carnegie

Eric Lavrut

Michael O'Keefe

John Barry Fitzgerald

Andrew J Parry

Gareth P Lees

Marian Faur

Francis Dominique Allouche

Bart V Thomeer

Michel V Berard

Warren Zemlak

Kay McGuinness

Theo Cuny

Mathilde Jan

Paul Frederick Cilgrim Dickenson

Moussa Kane

Richard Ferguson

Laurence Fraser

Carolina Dautriche

Steve Davies

Emma Irene Corcoran

Pierre-Jerome Acquaviva

Colin Whittaker

Chris Lenn

John Collins

A non-linear dynamic process such as multiphase flow is characterized to determine a condition of the process. A sensor may obtain information about strain, vibration, flow rate, etc. during the process. That sensor data may be plotted, and at least one perceptual hash can be generated from the plot. The perceptual hash can be compared against a database storing plots or hashes for non-linear dynamic responses for different sensor types or processes. A best fit hash may be identified and used to determine what conditions are occurring in the field, or multiple near fits can define an envelope of experimental/reference conditions with similar non-linear dynamics to the field system. Multiple hash comparisons may be used to refine the envelope, determine a best fit, or determine what measurement would help discriminate the flow conditions.

Dynamic systems and processes for determining a condition thereof

Provided herein are devices and methods for reducing the negative effects of bubble formation on the detection, quantification and/or monitoring of analytes.

Devices and methods for measuring analyte concentration

An electrochemical fluid sensor for a downhole production tool positionable in a wellbore penetrating a subterranean is provided. The wellbore has a downhole fluid therein. The electrochemical fluid sensor includes a sensor housing positionable in the downhole tool, a sensing solution positionable in the housing (the sensing solution including a mediator reactive to target chemicals), a gas permeable membrane to fluidly isolate the downhole fluid from the sensing solution (the gas permeable membrane permitting the passage of gas to the sensing solution), and a plurality of electrodes positioned about the housing a distance from the gas permeable membrane to measure reaction by the sensing solution whereby downhole parameters may be determined.

Downhole electrochemical fluid sensor and method of using same

A method is provided for determining a discharge coefficient of a managed pressure drilling choke/valve as a function of valve opening position. The method comprises: a flow of air/gas through the choke/valve; measuring a velocity of the air/gas flow at an inlet of the choke/valve; and measuring a pressure drop of the air/gas flow across the choke/valve.

Discharge coefficient determination of a managed pressure drilling choke/valve

Monitoring one or more items of equipment associated with a borehole or other conduit. A sensor system includes a vibration sensor for sensing vibrations at one or more sensor locations associated with one or more items of the equipment and/or the borehole or other conduit. A processing system processes the sensor information to determine a characteristic of the operation of the one or more items of equipment and/or the borehole or other conduit.

Monitoring of equipment associated with a borehole/conduit

A control line assembly and technique for fabricating the control line assembly are disclosed. The assembly includes drawn tubular segments through which a gas is flowed to purge contaminants. The outflow of contaminants due to the gas flow is monitored and the gas flow can be controlled and terminated when a sufficient quantity of contaminants has been extracted. The gas flow can be combined with a heat treatment cycle to further extract contaminants. The heat treatment cycle can include multiple heating stages that can be controlled based on the monitoring of the exiting contaminants.

Control line assembly and fabrication technique

A downhole densitometer is used to determine one or more characteristics of a flowing fluid. The densitometer has one or more downhole x-ray sources and one or more downhole x-ray detectors. A fluid is allowed to flow past the x-ray sources. X-rays emitted by the x-ray sources and that have travelled through the flowing fluid are detected by the x-ray detectors. Characteristics of the flowing fluid are determined based on the detected x-rays. The densitometer may also have reference detectors used to measure a reference signal. The measured reference signal is used to normalize source emissions. The densitometer may be used as a permanent monitor and it may be used in conjunction with other sensors such as a flow-rate sensor or a capacitance sensor. The x-ray source may be, for example, a pyroelectric source, a radioisotopic source, or a traditional x-ray tube source.

Downhole X-ray densitometer

A method for analyzing the reliability of a measured volumetric flow rate of a fluid in a gas outlet line of a gas-liquid separator is provided. In one embodiment, analyzing the reliability of the measured volumetric flow rate includes measuring a gas volume fraction of the fluid in the gas outlet line, comparing the measured gas volume fraction of the fluid to a threshold gas volume fraction level, and determining whether the measured volumetric flow rate of the fluid is reliable based on the comparison. Additional systems, devices, and methods are also disclosed.

Systems and methods for analyzing fluid from a separator

A multiphase flow meter comprising two Venturis separated by a choke. The choke may be varied to adjust the properties of the multiphase fluid flow being measured. The two Venturis may be identical and may be arranged horizontally with respect to the multiphase fluid flow. The choke may be a choke in a return line of a managed pressure drilling system.

Multiphase flowmeter

A Coriolis flow meter for measuring a liquid volume fraction of a multiphase flow. The Coriolis meter includes a vibrating measurement conduit through which the multiphase flow, a wet gas flow or the like, is flowed and measured and/or analyzed. Operation of the Coriolis flow meter includes obtaining a measure of the input energy required to vibrate the conduit and a measure of the vibrational energy of the conduit, and determining the liquid volume fraction of the wet gas flow from the input energy and the vibrational energy. The liquid volume fraction may be used to correct other measurements made by the Coriolis flow meter such as density or mass flow rate.

Coriolis flow meter

A backflow and flow rate control system, comprising: a flow restrictor; a flow regulator chamber located down-stream of the flow restrictor; a control chamber configured to receive a portion of the fluid from a location upstream of the flow restrictor; a moveable element with no sliding parts positioned between the control chamber and the flow regulator chamber, wherein the moveable element is configured to move in response to a difference in pressure between the flow regulator chamber and the control chamber; a flow rate regulator configured to control the flow rate of the fluid in response to the movement of the moveable element; and a non-return regulator coupled with the moveable element and configured to control back-flow of the fluid.

Backflow and flow rate control valve

Systems and methods are disclosed for measuring and/or monitoring concentrations of a dispersed phase in a fluid. A wettable surface may be used that is configured to be selectively wettable by the dispersed phase in the fluid being tested/monitored and the amount of or the rate of change of the wetting/deposition of the dispersed phase on the wettable surface is sensed and used to monitor the concentration of the dispersed phase.

System and method for measuring or monitoring of a low concentration dispersed phase

Methods and apparatus are described for sampling and diluting concentrated emulsions, which may be oil-in-water emulsions, water-in-oil emulsions, or other concentrated emulsions. One method embodiment of the invention comprises obtaining a sample of a concentrated emulsion comprising a dispersed phase and a continuous phase fluid; measuring droplet concentration of the dispersed phase in the sample; and for droplet concentration of the sample greater than about 1000 ppm, diluting the sample with substantially pure continuous phase fluid, forming a first diluted emulsion. Methods of the invention include those wherein the obtaining of a sample comprises opening a fluid connection to a flowing stream comprising the concentrated emulsion, wherein the obtaining and diluting steps occur in real time.

Methods and apparatus for sampling and diluting concentrated emulsions

A method and system is provided for measuring a flow rate of a gas/liquid flow. The method and system for measuring the flow rate include flowing a swirling gas/liquid flow separated into a gas core and a liquid outer layer through a conduit containing a constriction having a reduced conduit cross-section, measuring the differential gas core static pressure between a position upstream of the constriction and a position at the constriction, measuring a further quantity which provides the flow rate of the gas, the flow rate of the liquid, or a correlation between the flow rate of the gas and the flow rate of the liquid, and determining the flow rates of the gas and the liquid from the differential gas core static pressure and said measured further quantity.

Gas/liquid flow rate determination

A technique includes providing equipment downhole in a well to receive flows. The technique includes regulating a ratio of the flows in the well. The regulation includes regulating the ratio of the flows such that the ratio is substantially independent of pressures of the flows downstream of a point at which the regulation occurs.

Controlling flows in a well

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St. Neots, United Kingdom

Gary Martin Oddie