Abstract: Methods for classification of hydrocarbon mixtures that include performing two-dimensional gas chromatography on a hydrocarbon mixture to obtain a chromatogram using a two-dimensional gas chromatograph equipped with a flame ionization detector, a reversed phase column configuration with a primary mid-polar or polar column and a secondary non-polar column, and a standard mixture. Classification is performed in which groups of hydrocarbons are identified and labeled based on peaks associated with the standard mixture, after which a quantification process is performed.

Abstract: An open system pyrolysis of a first hydrocarbon source rock sample obtained from a natural system is performed within a pyrolysis chamber by maintaining the pyrolysis chamber at a substantially constant temperature. Hydrocarbons are recovered from the pyrolysis chamber released by the first hydrocarbon source rock sample. A thermo-vaporization is performed within the pyrolysis chamber on the pyrolyzed sample at a substantially constant temperature. A first hydrocarbon expulsion efficiency of hydrocarbon source rock is determined. A second hydrocarbon rock sample is ground to a grain size less than or equal to or less than 250 micrometers. A second pyrolysis is performed on the ground hydrocarbon source rock sample by maintaining the chamber at a substantially constant temperature. A second hydrocarbon expulsion efficiency of the hydrocarbon source rock in the natural system is determined. The first hydrocarbon expulsion efficiency is verified using the second hydrocarbon expulsion efficiency.

Abstract: An open system pyrolysis of a first hydrocarbon source rock sample obtained from a natural system is performed within a pyrolysis chamber by maintaining the pyrolysis chamber at a substantially constant temperature. Hydrocarbons are recovered from the pyrolysis chamber released by the first hydrocarbon source rock sample. A thermo-vaporization is performed within the pyrolysis chamber on the pyrolyzed sample at a substantially constant temperature. A first hydrocarbon expulsion efficiency of hydrocarbon source rock is determined. A second hydrocarbon rock sample is ground to a grain size less than or equal to or less than 250 micrometers. A second pyrolysis is performed on the ground hydrocarbon source rock sample by maintaining the chamber at a substantially constant temperature. A second hydrocarbon expulsion efficiency of the hydrocarbon source rock in the natural system is determined. The first hydrocarbon expulsion efficiency is verified using the second hydrocarbon expulsion efficiency.

Abstract: A method of monitoring a reformer unit is disclosed. The method includes analyzing at least one of the feedstock and the product stream. The analyzing includes performing a detailed hydrocarbon analysis of at least one of the feedstock and the product stream. The method further includes obtaining a one-dimensional output from the detailed hydrocarbon analysis and adjusting the one-dimensional output to produce a multi-dimensional equivalent output. Adjusting the one-dimensional output includes applying an appropriate correlation matrix to the one-dimensional output to produce the multi-dimensional equivalent output. The appropriate correlation matrix is selected based upon the characteristics of the feedstock and the particular refinery unit.

Abstract: The ratio of carbon to hydrogen in hydrocarbon samples is determined using gas chromatography and atomic emission detection. Comparison of the carbon to hydrogen ratio from different samples allows for qualitative determination of relative hydrogen content. Establishing a carbon to hydrogen ratio for a reference sample allows a further quantitative determination of carbon to hydrogen ratio.

Abstract: Processing a reservoir fluid sample includes separating the reservoir fluid sample into a vapor phase stream and a liquid phase stream, assessing a composition of the vapor phase stream, sampling a property of the liquid phase steam, and assessing a volume of a components of the liquid phase stream based at least in part on the sampled property of the liquid phase stream. A system for processing a reservoir fluid sample includes a volumetric receptacle adapted to accept the reservoir fluid sample, a phase separator configured to receive the reservoir fluid sample from the volumetric receptacle and to separate the reservoir fluid sample into a vapor phase stream and a liquid phase stream, a gas chromatograph arranged to receive the vapor phase stream from the phase separator, and a liquid flow meter configured to detect an interface including at least one component of the liquid phase stream.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to draw a formation fluid sample into a sampling port included in a down hole tool, to vaporize some part of the fluid sample to substantially fill an injection port with a gas phase, to differentiate gas components in the gas phase to provide differentiated gas components along a concentration gradient, to detect the differentiated gas components, and to determine a fingerprint of the differentiated gas components. Other apparatus, systems, and methods are disclosed.

Abstract: Example embodiments include one or more of a method, computing device, computer-readable medium and system for allocating oil production from geochemical fingerprints. In an example embodiment, a method may include providing a known mixture comprising known proportions of a plurality of end-members; providing an unknown mixture comprising unknown proportions of the end-members; performing a chromatographic analysis of each of the known mixture, the end-members, and the unknown mixture; determining a plurality of peak ratios, and prior peak ratio qualities related to the peak ratios, using the chromatographic analysis; and estimating an estimate of the unknown proportions of the end-members using the peak ratios, the prior peak ratio qualities, and the known proportion of the end-members.

Abstract: We provide an extracted conjunct polymer naphtha (45), comprising a hydrogenated conjunct polymer naphtha, from a used ionic liquid catalyst, having a final boiling point less than 246° C.(475° F.), a Bromine Number of 5 or less, and at least 30 wt % naphthenes. We also provide a blended alkylate gasoline (97 comprising the extracted conjunct polymer naphtha (45), and integrated alkylation processes to make the extracted conjunct polymer naphtha (45) and the blended alkylate gasoline (97). We also provide a method to analyze alkylate products, by determining an amount of methylcyclohexane in the alkylate products (80).

Abstract: Systems and methods are provided for analysis and/or profiling of petroleum samples. The systems and methods allow for compositional analysis of samples using techniques that can be implemented outside of a laboratory setting, such as in a refinery or even at a petroleum or hydrocarbon source. The techniques are enabled by using desorption electrospray ionization as a method for generating ions for detection by mass spectroscopy. Desorption electrospray ionization can be used to generate ions for detection from a liquid or solid petroleum (or other hydrocarbon) sample with minimal sample preparation. For solid samples, the technique can also be used to identify changes in composition of a petroleum sample relative to a dimension of the solid sample.

Abstract: The subject matter of the present disclosure is directed to developing a method of measuring the amount of producible oil and the producible oil saturation in shale-oil reservoirs using sample source rock. Further, the physical and chemical properties and amounts of producible oil in shale-oil reservoir samples may be determined. First and second solvents are applied to a sample source rock to extract petroleum from the sample source rock. The extracted source rock, the twice-extracted source rock, and the first and second extracted petroleum may be analyzed to determine the characteristics and properties of the reservoir rock.

Abstract: A miniaturized gas analyzer formed onto a micro-chip and a method of separating components from a composite gas using the miniaturized gas analyzer are disclosed. The gas analyzer includes an injector block and two column blocks arranged in series along an analytical path. The injector block receives the composite gas and a carrier gas to create a gas sample. The gas sample is then injected into the column blocks to separate the components of the composite gas. Further, a valve used within the miniaturized gas analyzer is disclosed, in which the valve is formed onto the micro-chip and includes a flexible membrane and a rigid substrate.

Abstract: A method and apparatus for providing compositional analysis of hydrocarbon fluids from well samples up to a C30+ fraction. The method includes the steps of heating a sample to a temperature of about 220° F., and collecting the liquid and gaseous fractions therefrom. Both the liquid and gaseous fractions are analyzed by gas chromatography. Additionally, the volume of the gas, and the volume, molecular weight and mass of the liquid are determined. The results are then analyzed to provide a total composition of the hydrocarbon fluids.

Abstract: The invention relates to a field gas chromatograph with flame ionization for the analysis of a gaseous mixture of hydrocarbons, extracted, in particular, from oil drilling mud. Said mixture consists of a fraction of heavy hydrocarbons (beyond pentane) dissolved in mud in gaseous form. Said field gas chromatograph is made up of two independent analysis circuits, dephased by half a cycle and synchronized one with the other. Said analysis circuits are comprised of at least one sampling cell in a preferred design layout, at least one capillary separation chromatography column, at least one flame ionization detector, and at least one electrometer for the conversion of an electrical current, collected by the flame ionization detector, into a voltage signal describing a chromatogram.

Abstract: Apparatus and systems, as well as methods, may operate to draw a formation fluid sample into a sampling port included in a down hole tool or tool body, to vaporize some part of the fluid sample to substantially fill an injection port with a gas phase, to differentiate gas components in the gas phase to provide differentiated gas components along a concentration gradient in a receiving section, to detect the differentiated gas components with a detector, and to determine a fingerprint of the differentiated gas components. A reaction section and a vacuum section may be used for waste consumption and/or absorption.

Abstract: The ratio of carbon to hydrogen in hydrocarbon samples is determined using gas chromatography and atomic emission detection. Comparison of the carbon to hydrogen ratio from different samples allows for qualitative determination of relative hydrogen content. Establishing a carbon to hydrogen ratio for a reference sample allows a further quantitative determination of carbon to hydrogen ratio.

Abstract: A gas chromatograph for analyzing natural gas, with a first separation column (6). A first detector (7) is provided following the first separation column, the first separation column and the first detector operable to separate or detect propane and higher hydrocarbons. A second separation column (8) and a second detector (9) following it are provided to separate or detect carbon dioxide and ethane. A third separation column (10) and a third detector (11) following it are provided to separate or detect nitrogen and methane. A controllable changeover device (12) is provided between the second separation column (8) and the third separation column (10) to discharge eluates following methane. The first, second and third separation columns (6, 8, 10) and the first, second and third detectors (7, 9, 11) are connected in series. At least the first and the second detectors (7, 9) are operable to detect a mixture of substances flowing through them in a non-destructive manner.

Abstract: A test method for the determination of methanol in crude oils to levels as low as 0.5 ppm is disclosed. The method includes extracting methanol into a water phase from a test sample of the crude oil forming a test sample extract. The method further includes extracting methanol into a water phase from a reference sample of the crude oil forming a reference sample extract, wherein the reference sample having a predetermined amount of methanol added thereto. The method further includes measuring the methanol content in the test sample extract and the methanol content in the reference sample extract. The method also includes determining the methanol content of the crude oil based upon the methanol content in the test sample extract and the methanol content in the reference sample extract.

Abstract: Apparatus and systems, as well as methods, may operate to draw a formation fluid sample into a sampling port included in a down hole tool or tool body, to vaporize some part of the fluid sample to substantially fill an injection port with a gas phase, to differentiate gas components in the gas phase to provide differentiated gas components along a concentration gradient in a receiving section, to detect the differentiated gas components with a detector, and to determine a fingerprint of the differentiated gas components. The receiving section may comprise a diffusion section. A reaction section and a vacuum section may be used for waste consumption and/or absorption.

Abstract: The present disclosure provides a method for detecting degradation of an engine oil, by separation into a polar component and a non-polar component via admixture with a polar solvent having a polarity index greater than or equal to 5 and optionally a non-polar solvent having a polarity index of less than or equal to about 1. The polar component is analyzed for one or more degradation indicators selected from the group consisting of antioxidants, acid content, and combinations thereof. Such degradation indicators relate to a degree of engine oil degradation. The polar component may be analyzed by Gas Chromatography and Mass Spectrometry (GC/MS) for the one or more degradation indicators, which can provide a semi-quantitative level of such degradation indicator species. The non-polar component identifies combustion products that help to explain the level of degradation.

Abstract: This unique process is a feed forward control of hydroprocessing by on-line sulfur speciation. An on-line gas analyzer such as (GC) with a sulfur specific detector (AED) would be installed to analyze the feed to a hydrotreating unit. The analyzer would be calibrated to quantify the individual sulfur compounds or classes of sulfur compounds present in the feed. The output from the analyzer would be linked to the unit's distributed control system to automatically change temperatures and feed rates to change hydrotreating severity. This invention could bring economical benefits by increasing the life of the hydrotreating catalyst, reducing operating cost, and decreasing the potential amount of offspec product. In one embodiment, the hydrotreating is a hydrodesulphurization process.

Abstract: The invention relates to a miniaturized gas chromatograph and injector for the same. Said micro-GC is compact and simple and economical to construct. Dead volumes are largely avoided in order to achieve reliable and reproducible measured results. Said miniaturized gas chromatograph comprises at least one injector, one separation column and a detector which are combined on a circuit board to give a gas chromatography module. The injector comprises a first sheet with channels, which is provided with a second sheet with channels and which may be displaced relative to the latter, whereby at least one of the sheets is provided with a layer of plastic, in particular a chemically inert plastic on the side of the sheet facing the other side.

Abstract: A method of estimating contamination of oil based mud filtrate in a hydrocarbon sample. The method comprising the steps of obtaining a hydrocarbon sample contaminated with oil based mud filtrate, then analyzing the contaminated hydrocarbon sample using two-dimensional gas chromatography (GC×GC). The method further comprises identifying one or more unique component or tracer in the oil based mud filtrate in the contaminated hydrocarbon sample. Finally, the method comprises of summing the peak volumes of the one or more unique component or tracer, relative to the peak volumes of a clean hydrocarbon sample.

Abstract: The present invention is a method to identify a refinery solid foulant of unknown composition including the following steps: obtaining a solid foulant sample, removing trapped feed from the sample with a solvent to obtain an insoluble sample, scanning the insoluble sample with a scanning electron microscope and energy dispersive x-rays, performing a thermal gravimetric analysis including an ash test on the insoluble sample to determine the presence of polymer, coke and inorganic elements, performing an elemental analysis on the insoluble sample for the elements carbon, hydrogen, sulfur, nitrogen, halogens, and metals, performing an optical microscopy on the insoluble sample to determine the presence of wax, asphaltenes, anisotropic coke and isotropic coke, and identifying the solid foulant.

Abstract: A method of determining physico-chemical properties of a petroleum sample from two-dimensional gas chromatography. The amounts of molecular compounds present in the sample are determined by means of two-dimensional gas chromatography. At least one physical property, such as the octane number, is then determined from these amounts. A previously calibrated relation connecting the physical property to the amounts is used to this end.

Abstract: The present invention provides apparatus and a methods for collecting, transmitting and storing fugitive gas emission data. An embodiment of the invention collects fugitive gas with a sampling probe and into a emission monitoring device. The device then sends and stores fugitive gas data into a storage medium, such as a wireless data-logging adapter. The wireless-data logging adapter stores the data and wirelessly sends it to a personal digital assistant or other form of redundant memory such as a data logger. In one embodiment, the PDA can initiate commands to retrieve data from the storage medium or operate the emission gas monitoring device.

Abstract: A method for the analysis by on-line gas phase chromatography of a gaseous phase produced by an olefin polymerization process which includes carrying out a chromatographic analysis of a gaseous phase produced by an olefin polymerization process with carrier gases containing mainly hydrogen and/or nitrogen, wherein the content of oxygen and of water of the hydrogen and the nitrogen in the carrier gases is less than 5 ppm by weight.

Abstract: A hydrocarbon detector (20) includes a gas stream delivery element (26) configured to discharge a carrier gas (70) onto a surface (24). The carrier gas (70) serves to volatilize a hydrocarbon presence (22) from the surface (24). A gas stream recovery element (28) is configured to aspirate a sample gas (78) formed from the carrier gas (70) combined with the hydrocarbon presence (22) volatilized from the surface (24). A hydrocarbon sensor (58) detects the hydrocarbon presence (22) in the sample gas (78) and generates an output signal indicative of the hydrocarbon presence (22). An indicator (80) receives the output signal and indicates the hydrocarbon presence (22) in the sample gas (78). A heat source (72) coupled to the gas stream delivery element (26) heats the carrier gas (70) to further aid in the volatilization of the hydrocarbon presence (22).