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: 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: 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: Method for preheating an oil reservoir comprises injecting saturated or superheated steam at an initial injection pressure into a tubing placed inside a well drilled in the oil reservoir. Steam temperature at an outlet of the tubing is measured and a heat flow from the well to the oil reservoir is calculated. An optimal steam injection rate when steam quality of the injected steam at the tubing outlet becomes greater than zero, is calculated, the optimal steam injection rate ensuring compensation of the heat flow from the well to the oil reservoir with the heat of steam condensation. A steam injection rate is decreased to the calculated optimal steam injection rate value by decreasing the initial injection pressure providing constant temperature at the outlet of the tubing.

Abstract: A system and method for showing heterogeneity of a porous sample by evaluating the porous sample to generate a digital core image, performing segmentations on the digital core image using multiple approaches to obtain a segmented volume, dividing the segmented volume into one or more sub-volumes of differing size, calculating one or more petrophysical or fluid flow parameters or porosity from the one or more sub-volumes, and presenting data as a structure composed of grid blocks representing an exact representation of the one or more sub-volumes positioned according to a spatial location of the one or more sub-volumes based on selected parameters or values from the one or more petrophysical or fluid flow parameters or porosity.

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 comprises measuring temperature along an injection well, measuring a steam quality and an injection rate at an inlet of the injection well and estimating a pressure distribution profile. Then a steam injection profile is estimated using the obtained pressure distribution profile and the measured injection rate combined with a one-dimensional injection well model for pressure losses in the well and heat exchange between an injection well tubing and an annulus. The obtained steam injection profile is used as an input parameter for a set of two-dimensional cross-sectional analytical SAGD models. The models are based on energy conservation law and take into account reservoir and overburden formation properties, heat losses into the reservoir and overburden formation impact on production parameters and SAGD characteristics. SAGD process characteristics are estimated from the set of two-dimensional cross-sectional analytical SAGD models.

Abstract: Method for preheating an oil reservoir comprises injecting saturated or superheated steam at an initial injection pressure into a tubing placed inside a well drilled in the oil reservoir. Steam temperature at an outlet of the tubing is measured and a heat flow from the well to the oil reservoir is calculated. An optimal steam injection rate when steam quality of the injected steam at the tubing outlet becomes greater than zero, is calculated, the optimal steam injection rate ensuring compensation of the heat flow from the well to the oil reservoir with the heat of steam condensation. A steam injection rate is decreased to the calculated optimal steam injection rate value by decreasing the initial injection pressure providing constant temperature at the outlet of the tubing.