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 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 method for determining equilibrium wettability of an interface between a void space and a solid phase of a rock sample comprises obtaining a three-dimensional image of the internal structure of the sample. On the obtained image of the internal structure of the sample, a void space and a solid phase are differentiated. An interface between the void space and the solid phase of the sample and distribution of minerals on this surface are determined. Wettability of the solid phase at each point of the interface between the void space and the solid phase of the rock sample is determined. A process of oil migration to the void space filled with stratum water at the initial stage of formation of an oil and gas field is numerically simulated, and finally, the equilibrium wettability of the interface between the void space and the solid phase of the rock sample is determined.

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: In order to determine characteristics of a gas-oil transition zone in a gas capped oil reservoir, samples of a reservoir fluid from a gas and an oil part of the reservoir are taken. To configure an equation of state of hydrocarbon mixtures, reservoir temperature and pressure are measured in places where the samples of the reservoir fluid are taken and densities and compositions of the samples are determined. Porosity, water saturation and total hydrogen content of a saturated rock are measured along the wellbore and a volume and a hydrogen content of hydrocarbon phases are determined. Using the equation of state, density and composition of the hydrocarbon phases are computed and a specific hydrogen content in gas and oil along the wellbore is determined. Gas and oil saturation distribution along the wellbore is determined from the determined specific hydrogen content, determined hydrogen content of the hydrocarbon phases and the measured porosity.

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 method for determining equilibrium wettability of an interface between a void space and a solid phase of a rock sample comprises obtaining a three-dimensional image of the internal structure of the sample. On the obtained image of the internal structure of the sample, a void space and a solid phase are differentiated. An interface between the void space and the solid phase of the sample and distribution of minerals on this surface are determined. Wettability of the solid phase at each point of the interface between the void space and the solid phase of the rock sample is determined. A process of oil migration to the void space filled with stratum water at the initial stage of formation of an oil and gas field is numerically simulated, and finally, the equilibrium wettability of the interface between the void space and the solid phase of the rock sample is determined.

Abstract: The invention allows determining a local change of an admixture concentration in a fluid flow at an entrance to a measurement cell. The change of the admixture concentration in time inside the measurement cell is first determined for a fluid containing the admixture, the change of concentration of which in time at the entrance to the measurement cell is known. Then, an impulse response of the cell is found applying the deconvolution method. The change of the admixture concentration inside the measurement cell is then determined for a fluid being studied with an unknown concentration of the admixture at the entrance. The unknown concentration is determined using the impulse response of the measurement cell and the change of the admixture concentration inside the cell.

Abstract: The disclosure relates to methods of logging wells for gas capped oil reservoirs with a known mineral composition of constituent rocks. For determining characteristics of a gas-oil transition zone at least one sample of a reservoir fluid from a gas part and from an oil part of the reservoir are taken. Reservoir temperature and pressure are measured in places where the samples of the reservoir fluid are taken and densities and compositions of the samples are determined. The determined densities and compositions and the measured pressure and temperature are used to configure an equation of state of hydrocarbon mixtures. Porosity, water saturation and a total hydrogen content of a saturated rock are measured along the wellbore. A volume of hydrocarbon phases is computed from the measured values of porosity and water saturation of the saturated rock, and a hydrogen content of the hydrocarbon phases is determined from the measured values of the total hydrogen content of the saturated rock.

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 of tracking a treatment fluid in a subterranean formation penetrated by a wellbore provides for injecting the treatment fluid with the plurality of tracer agents into the well and the formation. The tracer agents are high viscous liquid droplets having a diameter of not more than 1000 nm. Location and distribution of the treatment fluid is determined by detecting changes in physical properties of the formation caused by arrival of the treatment fluid comprising the plurality of the tracer agents.

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.

Abstract: This invention relates generally to methods for monitoring directional flood front movement during oil recovery and more specifically to methods for monitoring flood front movement of flooding agent injected into subsurface formations. The method comprises detecting physical properties of subsurface formation and injection of a flooding agent into said formation through at least one injection well thus forcing reservoir oil movement toward at least one production well. The flooding agent is a highly dispersed gas-liquid mixture having size of gas bubbles not exceeding an average diameter of the pores of said oil-bearing reservoir. The method further comprises detecting the same physical properties of the formation at the same area after flooding and monitoring the flood front profile by registrating changes in the physical properties of the formation caused by the arrival of said flood front.

Abstract: Methods for determining a quantitative composition of a multi-component medium comprising at least two known immiscible components comprises determining temperature dependencies of specific heat capacity of each of the components. A sample of the multi-component medium is weighed. Specific heat capacity of the sample is determined at least at i?1 temperature levels, where i is the number of components of the multi-component medium. On the basis of the results from determination of specific heat capacity of the components and the temperature dependencies of specific heat capacity of the components, weight coefficients are calculated for each component of the medium. Quantitative content of each of the components of the multi-component medium is determined on the basis of the obtained values of the weight coefficients of the components.

Abstract: The invention allows determining a local change of an admixture concentration in a fluid flow at an entrance to a measurement cell. The change of the admixture concentration in time inside the measurement cell is first determined for a fluid containing the admixture, the change of concentration of which in time at the entrance to the measurement cell is known. Then, an impulse response of the cell is found applying the deconvolution method. The change of the admixture concentration inside the measurement cell is then determined for a fluid being studied with an unknown concentration of the admixture at the entrance. The unknown concentration is determined using the impulse response of the measurement cell and the change of the admixture concentration inside the cell.

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: A method of tracking a treatment fluid in a subterranean formation penetrated by a wellbore provides for injecting the treatment fluid with the plurality of tracer agents into the well and the formation. Each tracer agent is an object of submicron scale. The location and distribution of the treatment fluid is determined by detecting changes in the physical properties of the formation caused by the arrival of the treatment fluid comprising a plurality of tracer agents.

Abstract: The invention is related to the development of volatile oil deposits and may be used to determine current gas saturation in a near-wellbore zone in a volatile oil formation. The method for the current gas saturation determination in the near-wellbore zone requires the measurement of the formation rock parameters and formation fluid parameters before the gas accumulation start in the near-wellbore zone and creation of the numerical model of the neutron logging signal change during the production period for the measured formation and formation fluid parameters and expected gas saturation value. During the production period when the well productivity decreases, neutron logging is performed and then the measured signals are matched with the model calculations and based on the provision of the best match of the measured and simulated neutron logging signals gas saturation is determined.