Schlumberger Technology Corporation

Schlumberger Technology Corpoation

Schlumberger Canada Limited

Prad Research and Development Nv

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Go Fujisawa

Oliver Clinton Mullins

Nathan Scott Lawrence

Chengli Dong

Sheng Chao

Li Jiang

Timothy Gareth Jones

Sophie Nazik Godefroy

Toru Terabayashi

Andrew L Kurkjian

Soraya Sofia Betancourt

Steven Antony Gahlings

Rolf Rustad

Julian J Pop

Tsutomu Yamate

Kentaro Indo

Stephane Vannuffelen

Ricardo Vasques

Andrew John Carnegie

Michael O'Keefe

Noriyuki Matsumoto

Hani Elshahawi

Maki Ikeda

Terizhandur S Ramakrishnan

Yi-Qiao Song

Kai Hsu

Peter D Wraight

Henri-Pierre Valero

Lalitha Venkataramanan

Peter S Hegeman

Bhavani Raghuraman

Timothy David Jones

Raghu Madhavan

Joel Lee Groves

Andrew Meredith

Felix K Chen

Jimmy Lawrence

Lennox Reid

Anthony Goodwin

John Allan Nighswander

Philip Rabbito

Hideki Kinjo

Richard Jackson

Michael M Toribio

Andrew Carnegie

Gary W Corris

ChengGang Xian

Michael Stangeland

Kazumasa Kato

Saifon Sirimongkolkitti

James J Dunlap

Fredrick A Jenet

Henning Groenzin

Hidetoshi Yoshiuchi

Ahmad Saputra

Yu Hatori

Mami Nishida

Chee Kin Khong

Maria A Van Agthoven

Satoko Yoshida

Peter S Hageman

Tim G J Jones

Jack H Harfoushian

Oliver C Mullins

Felix Chen

Gary Corris

Peter David Wraight

Michael O'KEEFE

A sensor for monitoring COin a fluid regardless of the phase properties of the fluid, i.e., regardless of whether the fluid contacting the window is a liquid water-based phase, a liquid oil-based phase, a mixture of liquid water and liquid oil-based phases, or a gas phase. The sensor includes an internal reflection window for contacting with the fluid. A mid-infrared light source directs a beam of mid-infrared radiation into the window and the beam is internal reflected at an interface between the window and the fluid. The reflected beam is passed through three narrow bandpass filters which preferentially transmit mid-infrared radiation over bands of wavelengths corresponding to absorbance peaks of water, oil and CO. The amount of COis determined from the intensities of the mid-infrared radiation passing through the three filters.

Mid-infrared carbon dioxide sensor

A sensor for monitoring COin a fluid regardless of the phase properties of the fluid, i.e., regardless of whether the fluid contacting the window is a liquid water-based phase, a liquid oil-based phase, a mixture of liquid water and liquid oil-based phases, or a gas phase. The sensor includes an internal reflection window for contacting with the fluid. A mid-infrared light source directs a beam of mid-infrared radiation into the window and the beam is internal reflected at an interface between the window and the fluid. The reflected beam is passed through three narrow bandpass filters which preferentially transmit mid-infrared radiation over bands of wavelengths corresponding to absorbance peaks of water, oil and CO. The amount of COis determined from the intensities of the mid-infrared radiation passing through the three filters

A sensor for monitoring a species which is a component of a fluid. The sensor includes an internal reflection window which, in use, is in direct contact with the fluid. The sensor further includes a mid-infrared light source which directs a beam of mid-infrared radiation into said window for attenuated internal reflection at an interface between the window and the fluid. The sensor further includes a first narrow bandpass filter which preferentially transmits mid-infrared radiation over a band of wavelengths corresponding to an absorbance peak of the species. The sensor further includes an infrared detector which detects filtered mid-infrared radiation transmitted through the first filter and a processor for measuring the intensity of the detected mid-infrared radiation transmitted through the first filter, and determines therefrom an amount of the species in the fluid.

Mid-infrared sensor

An integrated approach for cleaning an active surface of a petrochemical sensor. Sensors in the petrochemical industry are often deployed in locations where they are prone to fouling. By heating the active surface fouling substances may be removed from the active surface. Heating the surface above a supercritical point of a fluid being sensed may create a fluid that may serve to clean the active surface. Limiting the duration of the applied heating and/or pulsing the heating may mitigate adverse effects of use of high temperatures. A doped active surface, such as a doped diamond window may be designed to have conductive areas in the window that may be used for resistive heating of the window.

Active surface cleaning for a sensor

A sensor is provided for monitoring a mineral acid dissolved in a liquid. The sensor includes an internal reflection window which, in use, is in direct contact with the liquid. The sensor further includes a mid-infrared light source which directs a beam of mid-infrared radiation into said window for attenuated internal reflection at an interface between the window and the liquid. The sensor further includes a first narrow bandpass filter which preferentially transmits mid-infrared radiation over a band of wavelengths corresponding to an absorbance peak of the dissolved mineral acid to filter internally reflected mid-infrared radiation received from the window. The sensor further includes an infrared detector which detects filtered mid-infrared radiation transmitted through the first filter. The sensor further includes a processor arrangement, operably coupled to the infrared detector, which measures the intensity of the detected mid-infrared radiation transmitted through the first filter, and determines therefrom an amount of the mineral acid dissolved in the liquid.

Mid-infrared acid sensor

A gas separation and detection tool for performing in situ analysis of borehole fluid is described. The tool comprises a sampling chamber for a downhole fluid. The sample chamber comprises a detector cell with an opening. The tool also comprises a gas separation module for taking a gas from the downhole fluid. The gas separation module comprises a membrane located in the opening, a support for holding the membrane, and a sealant applied between the housing and the membrane or support. Moreover, the tool comprises a gas detector for sensing the gas.

Detecting gas compounds for downhole fluid analysis

A method and a tool that implements a method which includes measuring the viscosity and flow rates of formation fluids and obtaining the ratio of relative permeabilities of the formation fluids and wettability of the formation using the same.

Method for calculating the ratio of relative permeabilities of formation fluids and wettability of a formation downhole, and a formation testing tool to implement the same

Methods of and apparatus to estimate one or more volumes of one or more components of a fluid in a sample chamber of a downhole tool are described. An example method includes obtaining a sample chamber volume measurement, a flowline volume measurement and a supplemental volume measurement. The example method includes drawing the fluid into the sample chamber until the sample chamber is substantially full and measuring a characteristic of the fluid in the sample chamber at a first time to obtain a first characteristic measurement. The example method also includes adding a supplemental volume corresponding to the supplemental volume measurement to over-pressurize the sample chamber after measuring the characteristic at the first time and measuring the characteristic of the fluid in the sample chamber at a second time to obtain a second characteristic measurement. The second time is after the sample chamber is over-pressurized. In addition, the example method includes calculating a first volume of a first component of the one or more components of the fluid based on the first characteristic measurement, the second characteristic measurement, the sample chamber volume measurement, the flowline volume measurement and the supplemental volume measurement.

Methods and apparatus to estimate fluid component volumes

Methods of calibrating a fluid analyzer for use in a wellbore are described. An example method of generating calibration data for a fluid analyzer for use in a downhole tool involves lowering a downhole tool including a fluid analyzer to a location in a wellbore, measuring, via the fluid analyzer, a characteristic value of a calibration fluid or a vacuum while the fluid analyzer is at the location, obtaining an expected characteristic value for the calibration fluid or the vacuum at the location, and comparing the measured characteristic value to the expected characteristic value to generate a calibration value for the fluid.

Methods of calibrating a fluid analyzer for use in a wellbore

Methods and apparatus to use multiple sensors to measure downhole fluid properties are described. An example method of measuring a property of a downhole fluid involves obtaining a plurality of measurements for each of a plurality of sensors. Each of the measurements corresponds to a same property of the downhole fluid, and each of the sensors is differently configured to measure the property. Additionally, the example method involves obtaining a plurality of weighting values, each of which corresponds to one of the sensors. The example method also involves applying the weighting values to the respective measurements obtained by each of the corresponding sensors to generate a weight-corrected measurement for each of the sensors. Further still, the example method involves generating a value representative of a measurement of the property of the downhole fluid based on the weight-corrected measurements and outputting the value representative of the measurement of the property.

Methods and apparatus to use multiple sensors to measure downhole fluid properties

Vibrating wire viscometers are described. Some example vibrating wire viscometer housings include a flowline through the housing to expose a first wire to a downhole fluid, a cavity in the housing to hold a magnet and to conduct one or more additional wires from the flowline to a signal generator, first and second electrically conductive posts mechanically coupled to the housing to hold the first wire in tension within the flowline, and a seal mechanically coupled to the housing to prevent access to the magnet by the downhole fluid.

Vibrating wire viscometers

Vibrating wire viscometers are disclosed. An example vibrating wire viscometer includes first and second electrically conductive tubes, where the first tube is at least partially inserted into the second tube, and where the first and second tubes are coupled via an electrically insulating bonding agent. The example viscometer further includes first and second electrically conductive pins inserted into respective ones of the first and second tubes, and an electrically conductive wire fastened to the first and second pins to vibrate in a downhole fluid to determine a viscosity of the downhole fluid.

Methods and apparatus to determine a concentration of nitrogen in a downhole fluid are described. An example apparatus to determine a concentration of nitrogen in a downhole fluid includes a fluid measurement unit to measure a first fluid composition and a density of at least a hydrocarbon and carbon dioxide in a sample of the downhole fluid. Additionally, the example apparatus includes one or more sensors to measure at least a pressure and a temperature of the sample. Further, the example apparatus includes a processing unit to determine a first theoretical density based on at least the first fluid composition, the temperature, and the pressure the sample. Further still, the example apparatus includes an analyzer to determine a first difference between the density of at least the hydrocarbon and the carbon dioxide in the sample and the first theoretical density. The first difference is associated with a concentration of nitrogen in the sample.

Methods and apparatus to determine a concentration of nitrogen in a downhole fluid

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Sagamihara, Japan

Go Fujisawa