Abstract: Methods and systems for evaluating hydrocarbon in heterogeneous formations are disclosed. The use of three-dimensional simulation of the heterogeneous and porous structure at the nanometer scale of formation facilitates more accurate evaluation of the hydrocarbon reserve and fluid behavior.

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: A set of reservoir production results are obtained by simulation of hydrocarbons flow in a heterogeneous reservoir based on the values of heterogeneity blocks transport matrices. The transport matrices of the heterogeneity blocks are calculated from a reservoir block hierarchy. The simulation is initiated by a set of foundation blocks transport matrices calculated by evaluating a fluid transport law in the blocks being in the lowest rank of the hierarchy.

Abstract: A method includes receiving, via an network interface of a cloud-based infrastructure, a request for analysis of rock material properties based at least in part on a digital, image-based model of the rock material; responsive to the request, executing the analysis via provisioning of one or more resources of the cloud-based infrastructure to generate analysis results; and transmitting information based at least in part on the analysis results.

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 set of reservoir production results are obtained by simulation of hydrocarbons flow in a heterogeneous reservoir based on the values of heterogeneity blocks transport matrices. The transport matrices of the heterogeneity blocks are calculated from a reservoir block hierarchy. The simulation is initiated by a set of foundation blocks transport matrices calculated by evaluating a fluid transport law in the blocks being in the lowest rank of the hierarchy.

Abstract: The complex tool for well monitoring comprises a cylindrical housing and at least two lever centralizers aligning the tool along a well axis. Each centralizer has at least three levers, as well as at least one fluid flow temperature sensor, at least one phase composition sensor and at least one thermal flow velocity sensor, all sensors are located on an axis of the tool. The tool also comprises at least three groups of sensors distributed around a perimeter of the wellbore when the levers of at least one centralizer are being opened. Each group of the sensors comprises at least a fluid flow temperature sensor, a fluid phase composition sensor and a thermal flow velocity sensor, disposed on the same line parallel to the axis of the tool.

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: Studies of mechanical and thermal properties of materials. The method for determining a CLTE coefficient of a material comprises moving relative to each other a sample of the material and a source of heating a surface of the sample. While moving, the surface of the sample is heated with a periodic change in a density of a heating power, and an amplitude of deformation of the sample surface by heating is measured. Coefficient of linear thermal expansion is calculated based on measurement results and taking into account a density and a volumetric heat capacity of the sample. A device for determining CLTE comprises a platform for placing a sample of a material, a heating source configured to change a density of a heating power, at least one sample surface deformation amplitude sensor and a system for relative movement of the sample, the heating source and the surface deformation amplitude sensors.

Abstract: A sample of porous material is placed in a calorimeter cell and a pressure in the cell is increased starting from a pressure value of a first step by filling the cell with a wetting fluid. Measurements are taken of a heat flow to the cell and a fluid volume at each step. Then, the pressure in the cell is decreased to the pressure value of a first step with continued measurements of the heat flow to the cell. Increase and following decrease of the fluid pressure in the cell are repeated at least once. Then a temperature in the cell is decreased below a wetting fluid crystallization point. Once the fluid has been fully crystallized in sample pores, the temperature in the cell is increased above a wetting fluid melting point. Wetting limiting angle of the pores filled with fluid, and pore sizes are determined based on the results of heat flow measurements with due consideration of heat effect of fluid compression.

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: Estimating petrophysical properties of a hydrocarbon reservoir traversed by at least one wellbore comprises obtaining at least one core sample from the wellbore and obtaining a three-dimensional (3D) porous solid image of the core sample. A 3D pore scale model is generated from the 3D porous solid image. A distribution of reservoir fluids in pores of the reservoir is simulated by a microhydrodynamic simulation using the 3D pore scale models of the core samples and at least one petrophysical property of the reservoir by a microscale modeling using the simulated distribution of the reservoir fluids is simulated by fitting the at least one simulated petrophysical property to well logging data at a depth corresponding to a depth of taking the core sample using free parameters. Governing parameters of the 3D pore scale models are extrapolated along a logged part of the wellbore and the at least one other petrophysical property is estimated by simulation.

Abstract: A system for determination of a field rock type comprises a computer processor and a rock typing tool executing on the computer processor. The rock typing tool comprises a rock property database configured to store rock property data, a first module configured to receive new input field rock property data and a data processing module configured to characterize the new input field rock property data and to determine field rock type as a best matched rock type.

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: Method for determining wettability of porous materials comprises placing a sample of a porous material into a cell of a calorimeter and contacting the sample with a wetting fluid. A heat flow into the cell is continuously measured. Based on results of the measurement and taking into account a thermal effect of the fluid compression, a first wetting contact angle of pores filled with the wetting fluid is calculated. Then, a pressure in the cell containing the sample is increased starting from an initial value until pores of the sample are completely filled with the fluid. Then, the pressure is reduced to the initial value while continuously measuring of a heat flow into the cell. The method enables calculation of a second wetting contact angle for pores completely filled with the fluid and of a third wetting contact angle for pores free from the fluid.

Abstract: The downhole sensor is intended for measuring fluid flow parameters. It comprises two identical hollow metal housings opened at one end, whose symmetry axes are aligned. The open ends of the housings face each other and are rigidly fastened in the electrical insulator. A thermoanemometer sensor is arranged in each housing. Electrical leads of the sensors are within the cavities of the housings and extend outside through the electrical insulator.

Abstract: A sample of porous material is placed in a calorimeter cell and a pressure in the cell is increased starting from a pressure value of a first step by filling the cell with a wetting fluid. Measurements are taken of a heat flow to the cell and a fluid volume at each step. Then, the pressure in the cell is decreased to the pressure value of a first step with continued measurements of the heat flow to the cell. Increase and following decrease of the fluid pressure in the cell are repeated at least once. Then a temperature in the cell is decreased below a wetting fluid crystallization point. Once the fluid has been fully crystallized in sample pores, the temperature in the cell is increased above a wetting fluid melting point. Wetting limiting angle of the pores filled with fluid, and pore sizes are determined based on the results of heat flow measurements with due consideration of heat effect of fluid compression.

Abstract: A method for estimating properties of a subterranean formation penetrated by a wellbore provides for injecting a fluid with the plurality of tracer agents wherein each tracer agent is an object of submicron scale, into the wellbore and formation, flowing the fluid back from the subterranean formation and determining the properties of the formation. The properties are determined by analyzing changes in the tracers size and type distribution function between the injection fluid and produced fluid.

Abstract: This invention relates to a method of estimating fluxes for the processes of matter and field transport through fluid-saturated or gas-saturated porous solid. The method comprises obtaining three-dimensional porous solid images by, but not limited, X-ray microtomography, 3D NMR imaging, 3D reconstruction from petrographic thin-section analysis etc., digital processing and morphological analysis of the 3D core images by consecutive application of the image filtering, segmentation and multiple property recognition for obtaining digital 3D models of porous solid samples and performing a set of morphological and geometrical statistical property analysis. For the above mentioned 3D model (models) heat, mass, chemical and electric fluxes are modeled (separately or in combination) under given boundary conditions by means of numerical solver.