Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. A technique facilitates fluid analysis in situ at a downhole location. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. According to an embodiment, a sample of oil is obtained at the downhole location from oil in a reservoir. A downhole sampling system is used to determine whether a sample has contamination and other selected characteristics of the sample. The data obtained may be processed to provide a formation volume factor of the oil.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. A technique facilitates fluid analysis in situ at a downhole location. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. According to an embodiment, a sample of oil is obtained at the downhole location from oil in a reservoir. A downhole sampling system is used to determine whether a sample has contamination and other selected characteristics of the sample. The data obtained may be processed to provide a formation volume factor of the oil.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: A method for determining an asphaltene onset condition of a crude oil is provided. The method includes receiving a crude oil within a downhole tool inside a well and taking a first measurement of an optical property of the received crude oil. The method also includes lowering the pressure or temperature of the crude oil after taking the first measurement of the optical property to cause aggregation of asphaltenes in the crude oil, and then separating aggregated asphaltenes from the crude oil. Further, the method includes taking a second measurement of the optical property of the crude oil within the downhole tool after separating aggregated asphaltenes from the crude oil and determining an asphaltene onset condition of the crude oil through comparison of the first and second measurements of the optical property. Additional methods, systems, and devices are also disclosed.

Abstract: A method for determining an asphaltene onset condition of a crude oil is provided. The method includes receiving a crude oil within a downhole tool inside a well and taking a first measurement of an optical property of the received crude oil. The method also includes lowering the pressure or temperature of the crude oil after taking the first measurement of the optical property to cause aggregation of asphaltenes in the crude oil, and then separating aggregated asphaltenes from the crude oil. Further, the method includes taking a second measurement of the optical property of the crude oil within the downhole tool after separating aggregated asphaltenes from the crude oil and determining an asphaltene onset condition of the crude oil through comparison of the first and second measurements of the optical property. Additional methods, systems, and devices are also disclosed.

Abstract: Methods and systems for determining for determining asphaltene onset pressure of a formation fluid are described herein. The method includes the following processes: (a) transmitting light through a sample of the formation fluid; (b) decreasing pressure of the sample; (c) detecting intensity of the transmitted light during depressurization; (d) identifying a change in intensity of the transmitted light during depressurization; (e) increasing pressure of the sample to a fixed pressure; and (f) detecting intensity of the transmitted light at the fixed pressure and at an equilibrated light intensity. Processes (a) to (f) are repeated for a number of different fixed pressures. The asphaltene onset pressure of the formation fluid sample can be determined using (i) the intensity of the transmitted light during each depressurization and (ii) the intensity of the transmitted light at each of the different fixed pressures.

Abstract: Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid.

Abstract: A method for characterizing the dielectric response of a fluid includes receiving the fluid into a portion of a flow line that is disposed proximate to a photonic bandgap (PBG) resonant cavity so that a dielectric permittivity of the fluid affects a frequency response of the resonant cavity. The method further includes providing electromagnetic waves to the resonant cavity and measuring a frequency response of the resonant cavity in the presence of the fluid in the flow line. The method further includes determining a property of a resonant mode of the resonant cavity using the frequency response and determining a property of the fluid using the property of the resonant mode.

Abstract: A method and an apparatus for characterizing a fluid including a phase transition cell to receive the fluid, a piston to control fluid pressure, a pressure gauge to measure the fluid pressure and to provide information to control the piston, and connectors to connect the cell, piston, and gauge. The exterior volume of the phase transition cell, piston, gauge, and connectors is less than about 10 liters. A method and an apparatus to characterize a fluid including observing a fluid in an phase transition cell, measuring a pressure of the fluid, and adjusting a pressure control device in response to the measuring.

Abstract: An apparatus and a method including exposing a first fluid to a pre-filter, observing the first fluid, introducing a second fluid to the first fluid, exposing the first and second fluids to a filter, and observing the first and second fluids wherein the observing the first fluid and observing the first and second fluids comprise optical measurements and the first fluid comprises material from a subterranean formation. Some embodiments may compare the optical measurements of the first fluid and the first and second fluids and/or estimate the first fluid's likelihood of forming precipitants with other fluids and/or the first fluid's asphaltene content.

Abstract: Methods and systems for determining the presence and/or rate of a flow of a fluid sample include transmitting light through the fluid sample are disclosed. The methods comprise, applying a series of thermal pulses to the fluid sample, the series comprises a time interval between each thermal pulse, detecting transmitted light using a light detector; and determining at least one of (a) whether or not the fluid is flowing and (b) a flow rate of the fluid, based on an intensity of the transmitted light corresponding to at least one time interval.

Abstract: Methods and systems for determining for determining asphaltene onset pressure of a formation fluid are described herein. The method includes the following processes: (a) transmitting light through a sample of the formation fluid; (b) decreasing pressure of the sample; (c) detecting intensity of the transmitted light during depressurization; (d) identifying a change in intensity of the transmitted light during depressurization; (e) increasing pressure of the sample to a fixed pressure; and (f) detecting intensity of the transmitted light at the fixed pressure and at an equilibrated light intensity. Processes (a) to (f) are repeated for a number of different fixed pressures. The asphaltene onset pressure of the formation fluid sample can be determined using (i) the intensity of the transmitted light during each depressurization and (ii) the intensity of the transmitted light at each of the different fixed pressures.

Abstract: Methods and systems for determining asphaltene onset pressure of a formation fluid are disclosed herein. The method includes positioning a wellbore tool within a wellbore and drawing a formation fluid sample into the wellbore tool. The method further includes transmitting light through the sample and detecting light that is transmitted through the sample. The light is transmitted within the sample along a short path length of less than 2 mm. While the light is being transmitted, the pressure of the sample is varied. A wavelength dependent signal is determined using (i) the intensity of the transmitted light at a first wavelength and (ii) the intensity of the transmitted light at a second wavelength. The asphaltene onset pressure of the sample is determined by identifying a change in the wavelength dependent signal at a particular pressure.

Abstract: Systems and methods of determining fluid properties are disclosed. An example apparatus to determine a saturation pressure of a fluid includes a housing having a detection chamber and a heater assembly partially positioned within the detection chamber to heat a fluid. The example apparatus also includes a sensor assembly to detect a property of the fluid and a processor to identify a saturation pressure of the fluid using the property of the fluid.

Abstract: A method for characterizing the dielectric response of a fluid includes receiving the fluid into a portion of a flow line that is disposed proximate to a photonic bandgap (PBG) resonant cavity so that a dielectric permittivity of the fluid affects a frequency response of the resonant cavity. The method further includes providing electromagnetic waves to the resonant cavity and measuring a frequency response of the resonant cavity in the presence of the fluid in the flow line. The method further includes determining a property of a resonant mode of the resonant cavity using the frequency response and determining a property of the fluid using the property of the resonant mode.

Abstract: Systems and methods of determining fluid properties are disclosed. An example apparatus to determine a saturation pressure of a fluid includes a housing having a detection chamber and a heater assembly partially positioned within the detection chamber to heat a fluid. The example apparatus also includes a sensor assembly to detect a property of the fluid and a processor to identify a saturation pressure of the fluid using the property of the fluid.