Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Dmitry Anatolievich Koroteev

Igor Andreevich Varfolomeev

Alexander Nadeev

Sergey Sergeevich Safonov

Denis Klemin

Mark Andersen

Ivan Victorovich Yakimchuk

John Ratulowski

Oleg Dinariev

Evgeny Ivanov

Nikolay Vyacheslavovich Evseev

Dmitry Alexandrovich Korobkov

Andrey Vladimirovich Kazak

Alexander Nikolaevich Nadeev

Oleg Nikolaevich Zhuravlev

Andrei Alexandrovich Osiptsov

Irina Anatolievna Gorban

Ivan Viktorovich Yakimchuk

Denis Vladimirovich Klemin

Ivan Yakimchuk

A method for performing a simulation of a field having a subterranean formation is described. The method includes obtaining phase behavior data of subterranean fluids of the field, generating an equation of state (EOS) model of the fluids based on the phase behavior data, generating a Helmholtz free energy model that reproduces predictions of the EOS model over a pre-determined pressure and temperature range, and performing the simulation of the field using the Helmholtz free energy model. The method may further include reducing the EOS model to a reduced EOS model having a reduced number of components to represent the EOS model over a pre-determined pressure and temperature range, generating the Helmholtz free energy model based on the reduced EOS model, and obtaining and using phase behavior data of injection fluids used. A computer system data.

Construction of digital representation of complex compositional fluids

Evaluating structural changes in a sample resulting from a treatment of the sample. At least one sample of the material is scanned before and after the treatment and a first and a second image of the sample are obtained. The first and the second images are registered in a full spatial resolution using at least one region of the first image and at least one region of the second image, the regions corresponding to the same part of the sample. The registered images are analyzed and the changes in each sample caused by the performed treatment are evaluated.

Method for evaluating structural changes of a sample resulting from a treatment of the sample

A method and system for analysis of a digital core image obtained from a sample are disclosed. The method includes performing segmentations on the digital core image using multiple approaches to obtain multiple segmented images which are statistically analyzed to select the most suitable approach of the multiple approaches. Thereafter, a digital core model is generated using the segmented image corresponding to the most suitable approach. A simulation test may be performed on the digital core model to obtain a model test result and an oilfield operation may be performed based on the model test result. The system includes measurement and testing equipment to obtain the digital core image and a computing system including a data repository for storing a digital core image and a digital core model, and a digital core modeling tool. The digital core modeling tool performs the segmentations, statistical analysis, and generates the digital core model.

Digital core model construction

A method for estimating porosity of a rock sample comprises the steps of defining a total mineral content of a sample, determining relative volume fractions for each mineral and determining X-ray attenuation coefficients for the defined minerals. Then, a first X-ray attenuation coefficient for a synthetic sample combined from the same minerals with the same volume fractions but with no pores is determined. X-ray micro/nanoCT scanning of the sample is performed and a second X-ray attenuation coefficient for the rock sample is determined. Porosity can be calculated as for a sample filled with a gas, water or light hydrocarbons, so for a sample which pores are filled with heavy hydrocarbons, or other liquid/gases with X-ray attenuation coefficient comparable with X-ray attenuation coefficient for the rock sample or for the synthetic sample.

Method for estimating porosity of a rock sample

A method for building a 3D model of a rock sample comprises performing X-ray micro/nanoCT scanning of a rock sample and obtaining its initial three-dimensional microstructure image in a gray scale. Then, an analysis of the obtained three-dimensional image of the rock sample is performed and a binarization method is selected in dependence of the image quality and properties of the rock sample. The selected binarization method is at least once applied to the obtained initial three-dimensional image of the sample. Obtained 3D binarized image represents a 3D model of the rock sample.

Method for building a 3D model of a rock sample

Method of a formation hydraulic fracturing provides injection of a hydraulic fracturing fluid into a borehole with the increase of a fluid flow rate to a working value. During the injection a power consumption of a pump used for the injection is measured continuously. A pump power consumption jump indicates the fracturing fluid flow turbulization in the borehole.

Method of a formation hydraulic fracturing

A method includes installing at least one grounded electrode at a certain distance away from the well sufficient enough to avoid electrical breakdowns and connecting a high-voltage electric capacity meter to a wellhead and to said grounded electrode. A voltage pulse between the wellhead and the electrode. An electric capacity is measured before flooding and in the process of flooding. The oil formation water-flooding area radius value is determined by the flooded area capacity variation in time.

Method for determination of the oil formation's water-flooding area radius in the wellbore zone

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Moscow, Russia

Dmitry Anatolievich Koroteev