Abstract: A method and system that characterizes hydrogen sulfide in petroleum fluid employs a tool that includes a fluid analyzer for performing fluid analysis (including optical density (OD) for measuring carbon dioxide concentration) of a live oil sample, and a storage chamber for an analytical reagent fluidly coupled to a measurement chamber. An emulsion from fluid of the sample and the reagent is produced into the measurement chamber. The reagent changes color due to pH changes arising from chemical reactions between components of the sample and the reagent in the measurement chamber. The tool includes an optical sensor system that measures OD of a water phase of the emulsion at one or more determined wavelengths. The pH of the water phase is derived from such OD measurements. The pH of the water phase and the carbon dioxide concentration in the sample is used to calculate hydrogen sulfide concentration in the sample.

Abstract: A method includes receiving first fluid property data from a first location in a hydrocarbon reservoir and receiving second fluid property data from a second location in the hydrocarbon reservoir. The method includes performing a plurality of realizations of models of the hydrocarbon reservoir according to a respective plurality of one or more plausible dynamic processes to generate one or more respective modeled fluid properties. The method includes selecting the one or more plausible dynamic processes based at least in part on a relationship between the first fluid property data, the second fluid property data, and the modeled fluid properties obtained from the realizations to identify potential disequilibrium in the hydrocarbon reservoir.

Abstract: A method for determining reservoir architecture using modeling of a non-equilibrium distribution of at least one analyte in reservoir fluids. The analyte(s) of the analysis preferably has (have) significant compositional variation in the reservoir. For example, the analyte can be a later charging single gas component (such as methane, carbon dioxide, or hydrogen sulfide) in a multi-component fluid system. In this case, the model can assume that the components of the early charge are in a stationary state or in equilibrium, whereas the later charge is in a state of non-equilibrium. The non-equilibrium distribution of the analyte(s) derived from the model is compared to the distribution of the analyte(s) derived from downhole or laboratory fluid analysis of reservoir fluid, and the architecture of the reservoir is determined based upon such comparison.

Abstract: A method includes identifying linearly behaving data within obtained data associated with fluid obtained from a subterranean formation. Shrinkage factor is determined based on the linearly behaving data. A function relating GOR data of the obtained fluid with the determined shrinkage factor is determined. A first linear relationship between optical density (OD) data of the obtained fluid and the function is determined. A second linear relationship between density data of the obtained fluid and the function is determined. An oil-based mud (OBM) filtrate contamination property of OBM filtrate within the obtained fluid based on the first linear relationship is determined. A native formation property of native formation fluid within the obtained fluid based on the second linear relationship is determined. A volume fraction of OBM filtrate contamination within the obtained fluid based on the OBM filtrate contamination property and the native formation property is estimated.

Abstract: A method for determining reservoir architecture using modeling of a non-equilibrium distribution of at least one analyte in reservoir fluids. The analyte(s) of the analysis preferably has (have) significant compositional variation in the reservoir. For example, the analyte can be a later charging single gas component (such as methane, carbon dioxide, or hydrogen sulfide) in a multi-component fluid system. In this case, the model can assume that the components of the early charge are in a stationary state or in equilibrium, whereas the later charge is in a state of non-equilibrium. The non-equilibrium distribution of the analyte(s) derived from the model is compared to the distribution of the analyte(s) derived from downhole or laboratory fluid analysis of reservoir fluid, and the architecture of the reservoir is determined based upon such comparison.

Abstract: A method and system that characterizes hydrogen sulfide in petroleum fluid employs a tool that includes a fluid analyzer for performing fluid analysis (including optical density (OD) for measuring carbon dioxide concentration) of a live oil sample, and a storage chamber for an analytical reagent fluidly coupled to a measurement chamber. An emulsion from fluid of the sample and the reagent is produced into the measurement chamber. The reagent changes color due to pH changes arising from chemical reactions between components of the sample and the reagent in the measurement chamber. The tool includes an optical sensor system that measures OD of a water phase of the emulsion at one or more determined wavelengths. The pH of the water phase is derived from such OD measurements. The pH of the water phase and the carbon dioxide concentration in the sample is used to calculate hydrogen sulfide concentration in the sample.

Abstract: An air treatment apparatus has a housing and a vent cover. The housing has a treatment element, at least one entrance and a fan secured in the hollow housing and facing the entrance. The vent cover is detachably and replaceably attached to the housing. At least one vent is selectively defined in one of the top face and the front face of the vent cover. With such an air treatment apparatus, the vent cover can be interchanged between a jet-flow one or a laminar-flow one.

Abstract: An air treatment apparatus has a housing and a vent cover. The housing has a treatment element, at least one entrance and a fan secured in the hollow housing and facing the entrance. The vent cover is detachably and replaceably attached to the housing. At least one vent is selectively defined in one of the top face and the front face of the vent cover. With such an air treatment apparatus, the vent cover can be interchanged between a jet-flow one or a laminar-flow one.