Shell Oil Comapny

Shell Usa, Inc.

Krohne Ag

Shell Internationale Research Maatschappij, B.v.

John Justin Freeman

Matthias Appel

Daniel Pusiol

Nishank Saxena

Mariela Carpinella

Amie Marie Hows

Gabriela Albert

Stanley Nemec Milam

Ronny Hofmann

Irene Silvina Espejo Lopez Gamundi

Erik Willem Tegelaar

Tristán Martin Osán

Juan Manuel Ollé

Cornelis Johannes Hogendoorn

Rutger Reinout Tromp

Marco Leendert Zoeteweij

Juan Manuel Olle

Faruk Ömer Alpak

Richard Bruce Taylor

Tristan Osan

Irene Silvina Lopez Gamundi Espejo

Mario Winkler

Bernhard Peter Jakob Blumich

Bochao Zhao

Faruk ÖMer Alpak

The present invention provides a method for estimating fluid saturation of a hydrocarbon-bearing rock from a rock image. The image is segmented to represent either a pore space or solid material in the rock. An image pore volume is estimated from the segmented image, and a corrected pore volume is determined to account for the sub-resolution pore volume missing in the image of the rock. An image-derived wetting fluid saturation of the rock is estimated using a direct flow simulation on the rock image and corrected for the corrected pore volume. A backpropagation-enabled trained model can be used to segment the image. A backpropagation-enabled method can be used to estimate the fluid saturation using an image selected from a series of 2D projection images, 3D reconstructed images and combinations thereof.

Method for estimating fluid saturation of a rock

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

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 method of treating a wellbore penetrating a subterranean formation comprising: providing an asphaltene solvent, wherein the asphaltene solvent comprises at least 75 mol % dimethyl sulfide and introducing the asphaltene solvent into the wellbore.

Remediation of asphaltene-induced plugging of wellbores and production lines

A system and process for recovering oil from an oil-bearing formation. An oil recovery formulation that is first contact miscible with a liquid petroleum composition that is comprised of at least 15 mol % dimethyl sulfide is introduced together with steam or hot water into a subterranean oil-bearing formation comprising heavy oil, extra heavy oil, or bitumen, and oil is produced from the formation.

Oil recovery system and method

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

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.

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Pattison, TX, United States of America

John Justin Freeman