Shell Oil Comapny

Krohne Ag

Shell Usa, Inc.

Shell Internationale Research Maatschappij, B.v.

Matthias Appel

John Justin Freeman

Daniel Pusiol

Gabriela Albert

Mariela Carpinella

Ronny Hofmann

Nishank Saxena

Amie Marie Hows

Tristán Martin Osán

Juan Manuel Ollé

Irene Silvina Espejo Lopez Gamundi

Cornelis Johannes Hogendoorn

Rutger Reinout Tromp

Marco Leendert Zoeteweij

Juan Manuel Olle

Martin Alfred Kraaijveld

Andrew John Sederman

Bochao Zhao

Bernhard Peter Jakob Blumich

Mario Winkler

Irene Silvina Lopez Gamundi Espejo

Tristan Osan

Benjamin Charles Anger

Hilko De Jong

Lynn Faith Gladden

Nicholas Philip Ramskill

Michael David Mantle

Faruk ÖMer Alpak

The present invention provides a method for estimating the permeability of rock from a digital image of the rock. A three-dimensional image of a rock is obtained and segmented, and an image permeability is determined from the segmented image of the rock. Permeability correction factors are obtained from the segmented image and from a non-wetting liquid capillary pressure curve derived from the segmented image, and the permeability correction parameters are applied to the image permeability to obtain a corrected image permeability of the rock.

Method for digitally characterizing the permeability of rock

The present invention provides a method for determining the porosity of rock from a digital image of the rock. A three-dimensional image of a rock is obtained and segmented, and an image porosity is determined from the segmented image of the rock. A porosity correction parameter is obtained from a non-wetting liquid capillary pressure curve derived from the segmented image, and the porosity correction parameter is applied to the image porosity to obtain a corrected porosity of the rock.

Method for characterizing the porosity of rock

An imager and method for imaging fluid of a subsurface formation is disclosed. The imager includes a housing having a sidewall defining a passage to receive a core sample of the subsurface formation therethrough. The housing is positioned in a downhole tool and has a fluid inlet to receive fluid from the subsurface formation into the passage. The imager also includes a permanent magnet positioned in the sidewall of the housing, a radio frequency coil positioned in the sidewall of the housing between the permanent magnet and the passage, a gradient field in the sidewall of the housing between the permanent magnet and the radio frequency coil, and a chemically-selective imager. The chemically-selective imager is operatively connected to the radio frequency coil to selectively pulse frequencies according to a pulse sequence whereby individual fluid measurements of the sample are generated.

Chemically-selective imager for imaging fluid of a subsurface formation and method of using same

A nuclear magnetic flowmeter () for determining the flow of a medium flowing through a measuring tube () having a magnetic field generator (), a measuring unit () and an antennae unit () with an antenna (). wherein the antennae unit () has at least one further antenna (), that is designed as a coil and is designed for transmitting the excitation signal to the magnetized medium () and for detecting the measuring signal over a further measuring section () aligned parallel to the longitudinal axis () of the measuring tube and located in the magnetic field path (), and the measuring section () and the further measuring section () are different.

Nuclear magnetic flowmeter and method for operating nuclear magnetic flowmeters

A method for assessing a gas phase in a flowing multi-phase fluid comprises flowing the fluid through magnetic resonance and pre-polarization modules and applying to the fluid a radio-frequency pulse sequence at least once with and at least once without a magnetic field gradient. The method further includes measuring an NMR signal. The method also includes using a calibration between the ratio of slope and intercept of the NMR signal and flow velocity for at least one non-gas phase with the gradient applied to determine that phase's velocity. A calibration between the signal intensity of the liquid phases as function of flow velocity is used, with and without gradient, to correct the gradient-induced attenuation of the liquid signals and to calculate a gradient-corrected signal intensity of the liquid phases without a magnetic field gradient. Additionally, the method includes subtracting the gradient-corrected signal intensity from the NMR signal to calculate the volumetric fraction of the liquid phase.

Method of interpreting NMR signals to give multiphase fluid flow measurements for a gas/liquid system

A magnetic resonance based apparatus capable of measuring, without using time-of-flight measurements, flow regimes of multi-phase fluids in a pipe, comprises a magnetic resonance module through which the fluid phases flow, wherein the magnetic resonance module includes a radiofrequency coil for transmitting and detecting a signal and means for generating inside the module a homogenous constant magnetic field Bx that is thermally compensated and a transverse magnetic field gradient Gx that is superposed on Bx; and at least one pre-polarization module through which the fluid phases flow before entering the magnetic resonance module.

Method for analyzing a multi-phase fluid

A method for determining individual component flow-rates in a multi-phase fluid flowing in a pipe comprises the steps of: a) flowing the fluid through a magnetic resonance based apparatus comprising a magnetic resonance module and at least one pre-polarization module through which the fluid phases flow before entering the magnetic resonance module, wherein said pre-polarization module comprises a plurality of cylindrical segments that can be selectively combined so as to modify the effective length of the pre-polarization module, b) selectively using the prepolarization module to polarize a component in a volume of the fluid, c) applying a selective excitation to said fluid volume, d) using a signal resulting from said excitation to obtain a velocity measurement for said component, and e) repeating steps b)-d) until velocity measurements for a desired number of components have been obtained.

An apparatus and a method is provided based on the Magnetic Resonance techniques to analyze and measure a uni- and/or a bi-directional flow regime of multiphase fluids in a transport and production conduct, in real time and flow-rates, based on a magnetic resonance analytical module, two magnetic prepolarization modules of variable effective length and a control computer of data acquisition and transfer, all associated to each other.

Magnetic resonance based apparatus and method to analyze and to measure the bi-directional flow regime in a transport or a production conduit of complex fluids, in real time and real flow-rate

A method for measuring in situ formation fluid flow utilizing an NMR logging while drilling tool is disposed in the borehole, a modified saturation recovery or time of flight angiography pulse sequence is utilized to tag spins in the formation, at least two measurements are made of the tagged spins as they propagate toward the borehole in the under-balanced environment, allowing a determination of fluid velocity, from which permeability may be determined. Techniques are disclosed to perform the method in both an over-balanced and under-balanced environment.

NMR flow measurement while drilling

The present invention relates to a method and apparatus for measuring a property relating to fluid flow in an earth formation, more specifically to directly measuring formation permeability and other fluid characteristics. The present invention provides a method for determining the permeability of a hydrocarbon bearing earth formation, which method comprises the steps of: locating a tool at a selected position in a borehole penetrating the earth formation; inducing a flow of fluid within the earth formation to said tool; creating at least two MRI images of said fluid while flowing within the earth formation to said tool, said at least two images being created at different times; determining displacement of said fluid within the earth formation between said different times, using the at least two MRI images.

Method and apparatus for subterranean formation flow imaging

Growing community of inventors

Houston, TX, United States of America

Matthias Appel