Schlumberger Technology Corporation

Andrew John Carnegie

Oliver Clinton Mullins

Terizhandur S Ramakrishnan

Cosan Ayan

Fikri John Kuchuk

Raghu Ramamoorthy

Thomas J Neville

Benoit Couet

Chengli Dong

Go Fujisawa

William John Bailey

Michael David Prange

Raj Banerjee

Julian J Pop

Yi-Qiao Song

Kai Hsu

Tarek M Habashy

Dean M Homan

Tsutomu Yamate

Li Jiang

Edward Harrigan

Christopher Harrison

Kentaro Indo

Bhavani Raghuraman

Gary Martin Oddie

Stephane Vannuffelen

Anthony Louis Collins

Srinand Sreedharan Karuppoor

Roger Griffiths

Albert Ballard Andrews

Akira Kamiya

Mark A Fredette

Michael O'Keefe

Joseph Ayoub

Henry N Bachman

Peter Gerhard Tilke

Marian Faur

Andrei Davydychev

Jeffrey Spath

A Ballard Andrews

William B Vandermeer

Yves Barriol

Jeff Spath

Fikri Kuchuk

Luca Ortenzi

Michael Thambynayagam

R K Michael Thambynayagam

Gregory P Grove

Tim Hopper

ChengGang Xian

Marc Schneider

YuQiang Niu

Vijaya Halabe

Saifon Sirimongkolkitti

Jack H Harfoushian

Ibrahim Pamir Bursin

Stephen Flew

Jesus Alberto Canas Triana

Evie Freitas

ChenGang Xian

Jamil Al-Naser

Measuring a parameter characteristic of a formation in an oil well with a device configured to generate a sensing field within a volume of the formation and cause a flow through the volume in the presence of the sensing field. The device also comprises sensors responsive to changes in the volume, which indicate existent amounts of fluid, such as hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements may be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Formation treatment evaluation

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

Subsurface formation evaluation comprising, for example, sealing a portion of a wall of a wellbore penetrating the formation, forming a hole through the sealed portion of the wellbore wall, injecting an injection fluid into the formation through the hole, and determining a saturation of the injection fluid in the formation by measuring a property of the formation proximate the hole while maintaining the sealed portion of the wellbore wall.

Formation evaluation instrument and method

A system for automatically optimizing a Field Development Plan (FDP) for an oil or gas field uses a fast analytic reservoir simulator to dynamically model oil or gas production from the entire reservoir over time in an accurate and rapid manner. An objective function defining a Figure of Merit (FoM) for candidate FDPs is maximized, using an optimization algorithm, to determine an optimized FDP in light of physical, engineering, operational, legal and engineering constraints. The objective function for the Figure of Merit, e.g., net present value (NPV) or total production for a given period of time, relies on a production forecast from the fast analytic reservoir simulator for the entire FDP.

Automated field development planning

An apparatus and method of measuring a parameter characteristic of a rock formation in an oil well is provided with a device for generating a sensing field within a volume of the rock formation and a device for causing a flow through the volume in the presence of the sensing field, further including sensors responsive to changes in the volume, wherein a sensor response is indicative of the amounts of fluid, particularly hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements can be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Tool and method for determining formation parameter

A method of determining a selection of well measurements and/or their respective control parameters is described based on a global target having predetermined sensitivities to a multitude of uncertainties associated with input variables to a model including the step of ranking measurements and control parameters in accordance with their capability to reduce the uncertainties of input variables identified as most sensitive input variables through simulations using the model or a reduced variant of the model.

Method for selecting well measurements

A method is disclosed for modeling a first reservoir while drilling a wellbore into a corresponding second reservoir, the first reservoir having a plurality of stations, comprising: determining a plurality of values of net present value corresponding, respectively, to the plurality of stations of the first reservoir; and drilling the wellbore into the corresponding second reservoir in accordance with the plurality of values of net present value.

Method for determining a set of net present values to influence the drilling of a wellbore and increase production

A method, system and computer program product for simulating a fluid flow in a reservoir are disclosed. According to an embodiment, the current invention includes a method for simulating a fluid flow in a reservoir, the method comprising: providing an initial grid including multiple grid cells, each grid cell including a cell property; adjusting the initial grid to generated a modified grid in the case that a pressure equivalent radius under the initial grid is smaller than a well bore radius of the reservoir; and simulating the fluid flow in the reservoir based on the modified grid.

Simulating fluid flow in reservoir with modified grid

This relates to methods and apparatus for analyzing samples by fluorescence spectroscopy. In one embodiment, the methods and apparatus use a fluorescence detection unit (FDU) of a composition fluid analyzer (CFA&#x2122;) module to detect variations in fluid properties (gradients) within an oil bearing column. Some embodiments enable efficient downhole fluid analysis in heavy oils where water/oil emulsions are present (water in dispersed phase and oil in the continuous phase). The principles described herein may also be applied when there are fine particles in the oil such as from unconsolidated sands.

Methods and apparatus for analyzing fluid properties of emulsions using fluorescence spectroscopy

A method for data processing includes transforming measurement data acquired in the time domain during an oilfield operation into a second domain to produce transformed data; identifying distortions in the transformed data; removing the distortions from the transformed data; and transforming back from the second domain to the time domain to produce cleaned-up data. The transforming measurement data may use a Fourier transform or a wavelet transform. The method may further include compressing the cleaned-up data or reconstructing signals from the cleaned-up data. A method for data processing includes decomposing measurement data, which are acquired in an oilfield operation, using a low pass filter to produce a first dataset; decomposing the measurement data using a high pass filter to produce a second dataset; removing distortions from the second dataset to yield a corrected second dataset; and reconstructing a corrected dataset from the first dataset and the corrected second dataset.

Method, system and apparatus for formation tester data processing

A downhole fluid analysis tool capable of fluid analysis during production logging that includes a phase separator and a plurality of sensors to perform analysis on the fluids collected at a subsurface location in a borehole.

Downhole fluid analysis for production logging

A method for determining properties of a formation fluid is provided and includes: obtaining fluid data related to Carbon-Hydrogen molecular bonds in C+ from a fluid analyzer; and considering the fluid data to calculate mass fractions of hydrocarbon flowing through the fluid analyzer. The method further includes computing gas-oil-ratio of hydrocarbon based on the mass fractions of hydrocarbon. Another method for determining a gas-oil-ratio of a formation fluid includes: obtaining fluid data related to Carbon-Hydrogen molecular bonds in C+ from a fluid analyzer; considering the fluid data to derive mass fractions of gas and oil; and computing gas-oil-ratio of hydrocarbon based on the derived mass fractions.

Methods and apparatus for oil composition determination

A method for detecting pressure disturbances in a formation accessible by a borehole while performing an operation includes positioning a tool within the borehole, positioning a first probe of the tool at a first location, positioning a second probe of the tool at a second location remote from the first location to obtain a pressure reading, performing an operation with the first probe, detecting the presence of a first phase fluid within the tool, detecting a pressure disturbance within the formation with the second probe, and identifying a second phase fluid based on the detection of the pressure disturbance. Other methods and systems for detecting pressure disturbances in the formation are further shown and described.

System and method for detecting pressure disturbances in a formation while performing an operation

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Kuala Lumpur, Malaysia

Andrew John Carnegie