Abstract: A liquid additive mixing apparatus is provided that has a plurality of chambers containing additives, as well as a system for mixing the additives. One or more additives are mixed with water to form a mixing fluid. The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit. A cementing operation is executed during which the mixing fluid from the first tank is mixed with a cement to form a slurry. A capillary electrophoresis (CE) instrument is employed to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.

Abstract: Methods of treating an aqueous source are described herein that include reducing a concentration of sulfide species in a stream obtained from the aqueous source to form an extraction feed and extracting ions from the extraction feed, or a stream obtained from the extraction feed, using direct aqueous extraction. Other methods describe treating an aqueous source by reducing a concentration of organic species in a stream derived from the aqueous source to form an extraction feed and extracting ions from the extraction feed, or a stream derived from the extraction feed, using direct aqueous extraction. The aqueous source can be an aqueous lithium source.

Abstract: Methods may include emplacing a downhole tool within a wellbore, sampling a fluid downhole with the downhole tool; analyzing the fluid, and calculating an interfacial tension (IFT), wherein calculating the acid-base IFT contribution comprises measuring a concentration of a surface-active species directly. Apparatuses for measuring an interfacial tension (IFT) in a fluid downhole may be part of a downhole tool and may include a sampling head to sample the fluid; and a downhole fluid analysis module that includes a spectrometer capable of measuring a concentration of a surface-active species in the fluid, and a processor configured to determine the IFT of the fluid downhole based on the measured concentration of the surface-active species.

Abstract: A method of operating a drilling fluid analysis system includes obtaining multiple samples of a drilling fluid at different times over a time period. The method also includes placing the multiple samples into a capillary electrophoresis device. The method further includes determining a respective concentration of a component in each of the multiple samples of the drilling fluid with the capillary electrophoresis device.

Abstract: Systems and methods for monitoring a crude oil blending process use nuclear magnetic resonance (NMR) sensors which investigate properties of a plurality of crude oil streams that are mixed together to form a crude oil blend. An NMR sensor is also used to investigate the properties of the crude oil blend. The investigated properties may include viscosity. Resulting determinations may be used to control the input streams so that the output stream meets desired criteria. Additional sensors such as spectroscopy sensors, viscometers, and densitometers may be used in conjunction with the NMR sensors.

Abstract: A workflow and fluid analysis system to determine polar concentration and type of a reservoir fluid sample that is collected and analyzed in a downhole environment. Once collected this data can be fed into an advisory tool which can predict the probability of different types of issues that might be encountered in production of reservoir fluids from the reservoir. The workflow and fluid analysis system can also be employed in a surface-located laboratory tool for analysis of reservoir fluids.

Abstract: Methods and systems are provided for characterizing interfacial tension (IFT) of reservoir fluids, which involves obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions, and inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data. In embodiments, the fluid property data represents single-phase fluid properties of the reservoir fluid sample, such as fluid density and viscosity of an oil phase of the reservoir fluid sample and fluid density of a water phase of the reservoir fluid sample. In embodiments, the computation model can be based on machine learning or analytics combined with a thermodynamics-based physics model.

Abstract: Nuclear magnetic resonance (NMR) relaxation and/or diffusion measurements are used to deduce fluid compositional information such as a chain-length distribution, which may then be used to predict the true boiling points (TBP) of a sample of a complex hydrocarbon fluid mixture, such as a crude oil. The NMR measurements may be considered a fast and portable proxy measurement in estimating fluid TBP distributions in lieu of distillation methods, or the simulated distillation by gas chromatography.

Abstract: Methods and systems are provided for characterizing interfacial tension (IFT) of reservoir fluids, which involves obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions, and inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data. In embodiments, the fluid property data represents single-phase fluid properties of the reservoir fluid sample, such as fluid density and viscosity of an oil phase of the reservoir fluid sample and fluid density of a water phase of the reservoir fluid sample. In embodiments, the computation model can be based on machine learning or analytics combined with a thermodynamics-based physics model.

Abstract: The current application discloses methods and systems to analyze on-site and in real-time or quasi real-time the composition of the well fluid before or during use or disposition. The method is based on capillary electrophoresis (CE) and does not require the addition of tracers into the well fluid or additive. Based on the significance of each additive on the well fluid properties, it can be decided to determine the concentration of all additives or only one or a limited number of the additives present in the fluid, and the concentrations can be adjusted as needed to reach the desired target concentration(s).

Abstract: A liquid additive mixing apparatus is provided that has a plurality of chambers containing additives, as well as a system for mixing the additives. One or more additives are mixed with water to form a mixing fluid. The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit. A cementing operation is executed during which the mixing fluid from the first tank is mixed with a cement to form a slurry. A capillary electrophoresis (CE) instrument is employed to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.

Abstract: Nuclear magnetic resonance (NMR) relaxation and/or diffusion measurements are used to deduce fluid compositional information such as a chain-length distribution, which may then be used to predict the true boiling points (TBP) of a sample of a complex hydrocarbon fluid mixture, such as a crude oil. The NMR measurements may be considered a fast and portable proxy measurement in estimating fluid TBP distributions in lieu of distillation methods, or the simulated distillation by gas chromatography.

Abstract: Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Abstract: Systems and methods for monitoring a crude oil blending process use nuclear magnetic resonance (NMR) sensors which investigate properties of a plurality of crude oil streams that are mixed together to form a crude oil blend. An NMR sensor is also used to investigate the properties of the crude oil blend. The investigated properties may include viscosity. Resulting determinations may be used to control the input streams so that the output stream meets desired criteria. Additional sensors such as spectroscopy sensors, viscometers, and densitometers may be used in conjunction with the NMR sensors.

Abstract: Methods may include emplacing a downhole tool within a wellbore, sampling a fluid downhole with the downhole tool; analyzing the fluid, and calculating an interfacial tension (IFT), wherein calculating the acid-base IFT contribution comprises measuring a concentration of a surface-active species directly. Apparatuses for measuring an interfacial tension (IFT) in a fluid downhole may be part of a downhole tool and may include a sampling head to sample the fluid; and a downhole fluid analysis module that includes a spectrometer capable of measuring a concentration of a surface-active species in the fluid, and a processor configured to determine the IFT of the fluid downhole based on the measured concentration of the surface-active species.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Abstract: Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Abstract: A method of fluid testing includes pressurizing a fluid testing system, disposed at a subterranean location under high pressure compared to a surface pressure, to achieve a desired pressure differential between the high pressure and an internal pressure of the fluid testing system. The fluid testing system includes a capillary electrophoresis system and one or more test fluid reservoirs. The method also includes directing test fluid from the one or more test fluid reservoirs into capillaries to condition the capillaries. The method further includes directing sample fluid into the capillaries for testing while at the subterranean location.

Abstract: A method improves the capability for testing a fluid sample, e.g. testing a reservoir sample of hydrocarbon fluid. The methodology comprises positioning a capillary electrophoresis system within an enclosed chamber system. The enclosed chamber system preserves the desired downhole reservoir conditions during testing of the reservoir sample. In some applications, the reservoir sample is divided into a plurality of capillaries of the capillary electrophoresis system to enable testing of the reservoir sample with different types of detectors in one capillary electrophoresis system. The method can also be applied to depressurized reservoir samples.