Abstract: A quantitative simulation process for producing quantitative model predictions of hydrocarbon composition. The quantitative simulation may include measuring a chemical and isotopic composition of a hydrocarbon sample from a hydrocarbon reservoir.

Abstract: A method includes saturating a core sample with a hydrocarbon fluid to provide a hydrocarbon-saturated core, placing the core into a first aqueous fluid, applying an external force at increasing magnitude to the hydrocarbon-saturated core to displace a volume of the hydrocarbon fluid in the hydrocarbon-saturated core with the first aqueous fluid at each pressure magnitude, measuring a volume of displaced hydrocarbon fluid at each pressure magnitude, obtaining a first capillary pressure curve, re-saturating the core sample, placing the hydrocarbon-saturated core into a second aqueous fluid having a wettability altering agent, applying an external force at increasing magnitude to displace a volume of the hydrocarbon fluid in the core with the second aqueous fluid at each pressure magnitude, measuring a volume of displaced hydrocarbon fluid at each pressure magnitude, obtaining a second capillary pressure curve, and calculating a contact angle of the second aqueous fluid.

Abstract: An apparatus for determining the spatial distribution of materials within a sample using electromagnetic waves. The apparatus probes a sample with electromagnetic waves, measures the response, and determines the spatial configuration based on the measured response.

Abstract: A method for determining residual fluid saturation of a subsurface formation includes acquiring a sample of the subsurface formation, determining a first residual oil saturation during a water flooding process, determining a second residual oil saturation during a gas flooding process, determining a third residual oil saturation during an enhanced oil recovery (EOR) processes, and determining irreducible water saturation during an oil displacing water process.

Abstract: A method and system for determining contact angles of porous media, including: in a displacement simulation experiment, injecting a displacement fluid into a actual core sample, and performing computed tomography scanning on the core to determine three-dimensional images at different oil displacing time points; segmenting different phases of the three-dimensional images to obtain segmented three-dimensional images; marking a contact line between different phases according to the segmented three-dimensional images, where the phases are underground fluids or displacement fluids and a rock matrix in the displacement simulation experiment; and determining a contact angle of the porous media at different 3D positions at different time points according to the contact line. The method and system provided can obtain the dynamic changing process of the contact angle at different 3D positions in the core at different displacement time points, reflect the wettability of the real reservoir environment more accurately.

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: An apparatus for measuring permittivity of a sample. The apparatus includes: a sample chamber including a sealed space portion in which a sample to be measured is put; a pressure adjusting unit for varying pressure by applying water pressure to the space portion of the sample chamber; a permittivity sensor for measuring permittivity of the sample and disposed outside the sample chamber; measurement conducting wires including conductors, installed to contact the sample and connected to the permittivity sensor by using electric wires; and a data logger for storing data relating to permittivity that is measured by the permittivity sensor.

Abstract: An apparatus and method for simulating production conditions in hydrocarbon-bearing reservoirs, as an example, by flooding of core samples from such reservoirs, are described. Full recirculation flow measurements permit several fluids (for example, crude oil, brine, and gas) to be simultaneously injected into core samples having varying dimensions. Accurate and stable back pressures are maintained at total flow rates of as high as 200 cc/min., for a large range of fluid viscosities. Accurate and stable net overburden pressures relative to pore pressure are also maintained, thereby simulating the formations at depth. Core samples from formations may also be investigated using the apparatus and method hereof, for carbon dioxide sequestration potential, as another example.

Abstract: A wellbore fluid pressure measurement system includes a densometer adapted to measure a fluid density of a fluid flowing in a tubing system; and a monitoring unit communicably coupled to the densometer. The monitoring unit is adapted to receive a plurality of values representative of the fluid density from the densometer and includes a memory adapted to store the plurality of values representative of the fluid density; and one or more processors operable to execute a fluid pressure measurement module. The module is operable when executed to determine a fluid pressure of the fluid based on at least a portion of the values representative of the fluid density.

Abstract: Provided are an apparatus and a method for analyzing drilled submarine sediment on a ship. The apparatus includes: a core temperature measuring unit measuring temperatures of each portion of the drilled core positioned on a ship; a gas content analyzing unit analyzing a kind and a content of gases included in a submarine sediment sample collected from the drilled core in a state in which it is positioned on the ship; and a salinity measuring unit measuring salinity of the submarine sediment sample collected from the drilled core in a state in which it is positioned on the ship.

Abstract: A method for estimating properties of fluids in rock formations at selected locations within a geologic basin includes generating an initial model of the basin. The model includes as output spatial distribution of a rock formation mineral composition, rock formation porosity and composition of fluids in the rock formation porosity. An initial estimate of fluid composition is generated for a rock formation, and a sample of fluid is extracted from pore spaces of the rock formation. Composition of the fluid sample is analyzed from within, and the initial model of the basin is adjusted to substantially match the analyzed fluid composition. The adjusted model is used to generate an initial estimate of fluid composition.

Abstract: A method for characterizing a desired property of a fluid downhole is described. In some non-limiting examples, the method comprises receiving an input signal representing sound speed of a fluid downhole, processing the input signal using a correlation equation expressing the desired property in terms of at least sound speed to produce an output signal representing the desired property, and outputting the output signal. In some examples, the correlation equation is derived through a chemometric analysis of a training data set, the training data set comprises a plurality of input values and a plurality of output values derived from said input values, between the desired fluid property and the first measured property, and the output values are calculated from the input values using a series of correlation equations. In at least one example, the desired property is gas oil ratio. In another example, the desired property is gas brine ratio.

Abstract: In an oil sample analysis calculator (100) for analyzing results of oil samples from an engine, the oil sample analysis calculator (100) includes an input module (110) which receives an input data set (140), a processing module (130) which receives the input data set (140) from the input module (110) and corrects the input data set (140) based on at least one of an amount of oil added to the engine and an amount of oil removed from the engine, and an output module (120) which receives the input data set (140) corrected by the processing module (130) and outputs an output data set (150).

Abstract: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: The present invention relates to the use of an electronically controlled humidity chamber with temperature controls: to determine, by vapor desorption, high capillary pressures of core samples; to produce core samples with a high capillary pressure for testing electrical properties; and, using a curve of high capillary pressures from vapor desorption data, to transform a curve of high capillary pressures determined from high pressure mercury injection.

Abstract: The present invention relates to assays for ascribing catalytic activity to rock samples by virtue of zero-valent transition metals potentially being present within the sample. Embodiments of the present invention are generally directed to novel assays for measuring intrinsic paleocatalytic activities (k) of sedimentary rocks for converting oil to gas and projecting the activities to the subsurface based on the measured linear relationship between ln(k) and temperature (T).

Abstract: Exfiltrometer apparatus includes a container for holding soil. A sample container for holding sample soil is positionable with respect to the container so that the sample soil contained in the sample container is in communication with soil contained in the container. A first tensiometer operatively associated with the sample container senses a surface water potential at about a surface of the sample soil contained in the sample container. A second tensiometer operatively associated with the sample container senses a first subsurface water potential below the surface of the sample soil. A water content sensor operatively associated with the sample container senses a water content in the sample soil. A water supply supplies water to the sample soil. A data logger operatively connected to the first and second tensiometers, and to the water content sensor receives and processes data provided by the first and second tensiometers and by the water content sensor.

Abstract: Method and device for measuring the resistivity index curve (Ir) of a solid sample such as a geologic sample independently of the capillary pressure curve (Pc). Multi-frequency complex impedance measurements are carried out for a sample subjected to a radial confining pressure, during operations of drainage or imbibition of a first, initially saturating fluid, through a semipermeable membrane permeable to this first fluid, placed at a first end of a containment cell, by injection of a second fluid under pressure at the opposite end thereof. One or more injection pressure stages are applied and the continuous variations of the resistivity index (Ir) as a function of the average saturation (Sw) variation are measured without waiting for the capillary equilibria to be reached. Electrodes pressed against the sample on the periphery thereof are used, these electrodes having a given longitudinal extension in relation to the length of the sample and being connected to an impedance meter.

Abstract: An effective laboratory method for developing complete capillary pressure curves involves directly measuring an oil/water saturation profile within a cylindrical porous rock core plug. The saturation profile, which includes a free water level, is established under a known pressure gradient induced by centrifuging and is measured using image mapping techniques. The free-water level is established at a desired position within the length of the core plug and provides a reference position of zero capillary pressure to facilitate measurement of both positive and negative capillary pressures.