Abstract: 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.

Abstract: 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.

Abstract: Performing of a chemical treatment of a near wellbore area may include extraction of a core sample representing a portion of a near wellbore area, obtaining a three-dimensional (3D) pore scale model of a core sample, determination of composition of a core sample, generation scenarios of chemical treatment that each include chemical agent, determination of rates of reaction between mineral comprising core sample and treatment fluids, determination of qualitative and quantitative composition of reaction system in equilibrium, simulation of chemical treatment process using 3D model of a core sample and data on chemical reactions between minerals and treatment fluids, analysis of the chemical treatment influence on transport properties of a core sample, selection of optimal treatment scenario. Further, an operation is performed using the selected treatment scenario.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: Performing an enhanced oil recovery (EOR) injection operation in an oilfield having a reservoir may include obtaining a EOR scenarios that each include a chemical agent, obtaining a three-dimensional (3D) porous solid image of a core sample, and generating a 3D pore scale model from the 3D porous solid image. The core sample is a 3D porous medium representing a portion of the oilfield. The 3D pore scale model describes a physical pore structure in the 3D porous medium. Simulations are performed using the EOR scenarios to obtain simulation results by, for each EOR scenario, simulating, on the first 3D pore scale model, the EOR injection operation using the chemical agent specified by the EOR scenario to generate a simulation result. A comparative analysis of the simulation results is performed to obtain a selected chemical agent. Further, an operation is performed using the selected chemical agent.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: The method for 3D mineral mapping of a rock sample comprises the steps of defining a total mineral content of a sample and calculating X-ray attenuation coefficients for the defined minerals. X-ray micro/nanoCT scanning of the sample is performed and its three-dimensional microstructure image in gray scale is obtained. Characteristic grayscale levels in the image corresponding to calculated X-ray attenuation coefficients and accordingly to the minerals are allocated and the 3D mineral map of the interior of the sample is provided.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: The method for the determination of an oil formation's water-flooding area pattern and size in a borehole zone comprises grounded electrode installation at a certain distance away from the borehole sufficient enough to avoid electrical breakdowns. An electrical pulse generator is connected to a wellhead and to the electrode. A voltage pulse is applied between the wellhead and the electrode and electrical and/or acoustic response to electrical disturbances are measured. Pattern and size of the oil formation's water-flooding area is determined by an acquisition and processing system using a 4D seismic method. This method is technically simple to implement and may be applied under different field conditions.