Abstract: An analysis apparatus (100) includes an image acquisition unit (110) and an analysis unit (120). The image acquisition unit (110) acquires image data of a microfossil in a sample collected from a stratum. The analysis unit (120) analyzes the image data acquired by the image acquisition unit (110) using a machine learning result to analyze a taxon or kind of the microfossil in the image data.

Abstract: A method may comprise sampling a wellbore fluid; analyzing the wellbore fluid and determining a presence of a graphene-like substrate, a concentration of the graphene-like substrate, or both, in the wellbore fluid; and correlating the presence and the concentration of the graphene-like substrate to at least one subterranean formation characteristic.

Abstract: The invention is a method for determining at least one of the quantity and the quality of the hydrocarbons generated by maturing of the organic material of a mother rock of a sedimentary basin based on values representing the artificial maturation of an immature sample representing the mother rock and a sequence of artificial maturing temperatures. The method according to the invention determines the values of the kinetic parameters of a reaction rate law by minimizing simultaneously: (i) a difference between the values predicted by the reaction rate law applied with a historical record of temperatures of the basin determined by basin simulation and the measurements of the advance of the maturation of the organic material and (ii) a difference between the values predicted by the reaction rate law applied according to the sequence of temperatures for the artificial maturing and the values representing the artificial maturing.

Abstract: Disclosed herein is a variable soil sampling device which may be customized with respect to sampling rate and sorbent material used. Multiple variable sampling devices may be attached to each other to simultaneously sample different components or contaminants in the same time period.

Abstract: The invention provides a sampling apparatus for sampling fluid from a pipeline system during a pigging operation and a method of use. The sampling apparatus comprises an inlet configured to be coupled to the pipeline system, for receiving a fluid carried by a pigging operation from the pipeline system, and an outlet for discharging fluid from the sampling apparatus. A flow control valve is disposed between the inlet and the outlet. A first flow line is in communication with a sampling circuit and is disposed between the inlet and the flow control valve. A second flow line is in communication with a sampling circuit, and is disposed between the outlet and the flow control valve. The flow control valve is operable to be partially closed to create a pressure differential between the first and second flow lines, and drive a fluid passing through the sampling apparatus into the sampling circuit.

Abstract: Predicting and quantifying free silicon in a geological formation generates free silicon data for a physical sample obtained from within the geological formation. The free silicon data include identification of portions of the physical sample containing free silicon and a quantification of the free silicon contained in the portions of the physical sample containing free silicon. A modified petro-elastic model for the geological formation comprising rock constituents is generated that incorporates free silicon as one of the rock constituents and that quantitatively models how free silicon changes elastic properties within the geological formation. A three-dimensional model of the geological formation is created that indicates volumes of free silicon throughout the geological formation. The three-dimensional model is created using geophysical data obtained from the physical sample, seismic data covering the geological formation and the modified petro-elastic model.

Abstract: The present invention includes a method for determining the level of deep gas in a near surface formation that includes: measuring CO2, O2, CH4, and N2 levels in percent by volume from one or more surface or near surface geological samples; adding the water vapor content to the measured CO2, O2, CH4, and N2 levels in percent by volume; normalizing the gas mixture to 100% by volume or 1 atmospheric total pressure; and determining the ratios of: O2 versus CO2 to distinguish in-situ vadose zone CO2 from exogenous deep leakage CO2; CO2 versus N2 to distinguish whether CO2 is being removed from the near surface formation or CO2 is added from an exogenous deep leakage input; or CO2 versus N2/O2 to determine the degree of oxygen influx, consumption, or both; wherein the ratios are indicative of natural in situ CO2 or CO2 from the exogenous deep leakage input.

Abstract: A process for refining crude oil can be controlled to mitigate fouling by deploying a refractive index probe at a location suitable for making a crude oil stability determination, wherein the crude oil stability determination is relevant to controlling the refining process; making a measurement of crude oil stability; and then controlling the process for refining crude oil by maintaining the process or implementing a change to the process, based upon the determination of crude oil stability. This concept can also be applied to transporting, blending, and storing crude oil.

Abstract: Molecular structures of organic molecules in a geological formation are determined. The organic molecules may include kerogen, coal, and/or other organic molecules. In particular, the technique implemented may operate to convert nuclear magnetic resonance data into a multi-dimensional space that permits identification of molecular structures through comparisons of intensity information across the multi-dimensional space with a cutoff map of the space. This may not only simplify the identification of molecular structures of the organic molecules, but also use exact mathematical model for mixture samples to derive both structural and dynamic parameters plus their variation.

Abstract: A method for disabling and re-enabling third-party advertisements is disclosed. An Internet accessible “virtual world” or interactive on-line community can have its advertisements disabled by the entering and subsequent validation of a registration code that is associated with a toy into a website, once validated, displaying a virtual representation of the toy on the website, providing virtual world content so that the virtual representation of the toy is caused to interact with the virtual world content and the toy virtual representations of other users, displaying advertisement on the website in a first mode and allowing customization of the virtual world content including the disabling of advertisements in a second mode. In a similar manner the third party advertisements can be re-enabled.

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: The present invention includes a method for determining the level of deep gas in a near surface formation that includes: measuring CO2, O2, CH4, and N2 levels in percent by volume from one or more surface or near surface geological samples; adding the water vapor content to the measured CO2, O2, CH4, and N2 levels in percent by volume; normalizing the gas mixture to 100% by volume or 1 atmospheric total pressure; and determining the ratios of: O2 versus CO2 to distinguish in-situ vadose zone CO2 from exogenous deep leakage CO2; CO2 versus N2 to distinguish whether CO2 is being removed from the near surface formation or CO2 is added from an exogenous deep leakage input; or CO2 versus N2/O2 to determine the degree of oxygen influx, consumption, or both; wherein the ratios are indicative of natural in situ CO2 or CO2 from the exogenous deep leakage input.

Abstract: The invention is a method of predicting the amount and the composition of fluids produced by mineral reactions operating within a sedimentary basin and trapped with hydrocarbons in reservoirs. Geological data characteristic of the basin are acquired and a representation of the basin by a grid is constructed. The evolution of a depth of burial (z), a temperature (T), a pore pressure (P), a volume (V) and a porosity ? at successive ages (ti) representative of the geological history of the basin is then calculated for at least one set of cells of the grid, using a basin model and the geological data. A mineralogical or chemical rock composition is determined in each cell of the set of cells from the geological data of the basin. The amount and the composition of fluids of mineral origin is determined within the set of cells using a geochemical model and an equation of state, from the parameters, the composition and a thermodynamic database.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to acquire fluid image information from an imaging device having a field of view including fluid, the fluid image information including fossil image information. Additional activities may include processing the fossil image information to identify fossil types in the fluid as data that associates the fossil types with a formation from which the fluid was acquired, determining the location of a first borehole in the formation based on the data and offset records associated with a second borehole, and publishing the data in conjunction with indications of the location. Additional apparatus, systems, and methods are disclosed.

Abstract: Methods and apparatus for obtaining a mass spectrum of a sample and determining a concentration of a component of the sample by utilizing a model of chemical and electron ionization and the obtained mass spectrum.

Abstract: A method for estimating characteristics of a formation including collecting a formation sample, preparing the sample, and analyzing the sample using FTIR comprising identifying the kerogen lineshape and intensity. The method includes using the lineshape to obtain kerogen maturity, using the maturity to obtain the kerogen spectrum, and using the kerogen spectrum to obtain the mineralogy and kerogen content.

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: Methods of identifying geological materials of interest comprising (i) providing a nanoprobe composition comprising one or more nanoprobes; wherein the nanoprobe includes (a) at least one tag; and (b) at least one signal generator; (ii) introducing the nanoprobes to a geological material; and (iii) detecting the presence of a signal generated by the signal generator on association of the tag with a target. Nanoprobe compositions identify geological materials, systems include such nanoprobe compositions, and methods use such nanoprobe compositions for the evaluation of geological materials.

Abstract: Disclosed herein is a method involving the steps of (a) precipitating an amount of asphaltenes from a liquid sample of a first hydrocarbon-containing feedstock having solvated asphaltenes therein with one or more first solvents in a column; (b) determining one or more solubility characteristics of the precipitated asphaltenes; (c) analyzing the one or more solubility characteristics of the precipitated asphaltenes; and (d) correlating a measurement of feedstock reactivity for the first hydrocarbon-containing feedstock sample with a mathematical parameter derived from the results of analyzing the one or more solubility characteristics of the precipitated asphaltenes. Determined parameters and processabilities for a plurality of feedstocks can be used to generate a mathematical relationship between parameter and processability; this relationship can be used to estimate the processability for hydroprocessing for a feedstock of unknown processability.

Abstract: A method for estimating characteristics of a formation including collecting a formation sample, preparing the sample, and analyzing the sample using FTIR comprising identifying the kerogen lineshape and intensity. The method includes using the lineshape to obtain kerogen maturity, using the maturity to obtain the kerogen spectrum, and using the kerogen spectrum to obtain the mineralogy and kerogen content.

Abstract: Disclosed herein is a method involving the steps of (a) precipitating an amount of asphaltenes from a liquid sample of a first hydrocarbon-containing feedstock having solvated asphaltenes therein with one or more first solvents in a column; (b) determining one or more solubility characteristics of the precipitated asphaltenes; (c) analyzing the one or more solubility characteristics of the precipitated asphaltenes; and (d) correlating a measurement of feedstock reactivity for the first hydrocarbon-containing feedstock sample with a mathematical parameter derived from the results of analyzing the one or more solubility characteristics of the precipitated asphaltenes.

Abstract: Disclosed herein is a method involving the steps of (a) precipitating an amount of asphaltenes from a liquid sample of a first hydrocarbon-containing feedstock having solvated asphaltenes therein with one or more first solvents in a column; (b) determining one or more solubility characteristics of the precipitated asphaltenes; (c) analyzing the one or more solubility characteristics of the precipitated asphaltenes; and (d) correlating a measurement of feedstock fouling tendency for the first hydrocarbon-containing feedstock sample with a mathematical parameter derived from the results of analyzing the one or more solubility characteristics of the precipitated asphaltenes.

Abstract: A method for calculating the volume of various predetermined organic end-members in samples of rock at various depths in oil reservoir rock is utilized to produce one or more graphic displays that are use to interpret the data to identify, e.g., tar mats, in order to improve the efficient production of hydrocarbons from the well. Data is collected from the samples by known pyrolysis and compositional modeling methods; additional data is obtained by elemental analysis to determine weight percentages of C, H, N, S and O in the selected end-members and characterization of physical properties of representative samples of the reservoir rock, e.g., from core samples; the data is then processed in accordance with the method to provide a series of data points used to produce the graphic displays for visual interpretation.

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 present invention relates to methods for performing surveys of the genetic diversity of a population. The invention also relates to methods for performing genetic analyses of a population. The invention further relates to methods for the creation of databases comprising the survey information and the databases created by these methods. The invention also relates to methods for analyzing the information to correlate the presence of nucleic acid markers with desired parameters in a sample. These methods have application in the fields of geochemical exploration, agriculture, bioremediation, environmental analysis, clinical microbiology, forensic science and medicine.

Abstract: A method of playing a wagering game comprises receiving a wager, and generating a randomly selected first outcome of a first wagering game, the first outcome comprising a first plurality of symbols arranged in a first matrix. The method further comprises generating a randomly selected second outcome of a second wagering game, the second outcome comprising a second plurality of symbols arranged in a second matrix, and simultaneously displaying the first outcome and the second outcome on at least one display. The method further comprises detecting an occurrence of a triggering event, in response to the triggering event, copying a first special symbol occurring in the first outcome into the second outcome to yield a modified second outcome, and evaluating the first outcome and the modified second outcome for winning combinations of symbols.

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: A formation fluid sampling tool is provided with reactants which are carried downhole and which are combined in order to generate heat energy which is applied to the formation adjacent the borehole. By applying heat energy to the formation, the formation fluids are heated, thereby increasing mobility, and fluid sampling is expedited.

Abstract: A composition containing a petroleum hydrocarbon, a biodiesel fuel or an ethanol fuel, and an organic marker compound.

Abstract: A method and composition for identifying chemically tagged petroleum products can be achieved by adding one or more chemicals to a selected petroleum product wherein the chemical is immune to extraction from the petroleum product by conventional inexpensive absorbents, cannot be removed by extraction with acids, bases, or immiscible solvents, cannot be easily oxidized, reduced or reacted with common agents, is difficult to disguise by masking with other agents, has a low polarity, and has a boiling point in the range of the petroleum products the chemical is being added to. The presence of the chemical is determined by using ion mobility spectroscopy.

Abstract: A system for determining parameters and compatibility of a substance such as an asphalt or other petroleum substance uses titration to highly accurately determine one or more flocculation occurrences and is especially applicable to the determination or use of Heithaus parameters and optimal mixing of various asphalt stocks. In a preferred embodiment, automated titration in an oxygen gas exclusive system and further using spectrophotometric analysis (2-8) of solution turbidity is presented. A reversible titration technique enabling in-situ titration measurement of various solution concentrations is also presented.

Abstract: Apparatus, systems and methods for a gaming device operable to support a negative credit balance. For example, in some embodiments, a gaming device may be configured to: (i) determine a current credit balance, (ii) determine a wager amount, (iii) determine whether the wager amount would result in a negative balance of credits, (iv) determine if it is permissible to allow a negative balance of credits, and if so (v) adjust a current balance such that is equal to the negative balance, and (vi) display an indication of the negative credit balance.

Abstract: A method of determining the effect of a spill on a marine environment, in which physical and chemical sensors are arranged with living organisms (4, 6) fitted with instruments, at an appropriate distance and position from the object (1) which is to be monitored, wherein the response of the living organism (4, 6), measured online in real time, is compared with known patterns of response, and where upstream and downstream measurements are compared to determine whether a change in response may be caused by a spill from the object, the significance of the real time measurements being validated through sampling of the organisms on a regular basis or as required, in order to analyze the effects on the health of the organisms, biomarkers, for the purpose of assessing the significance of the environmental effect.

Abstract: The diffusion coefficients and relaxation times of mixtures of alkanes follow simple scaling laws based on the chain length of the constituents and the mean chain length of the mixture. These scaling laws are used to determine chain sizes in a mixture from the distribution of the diffusion coefficients. These scaling laws can be used to determine the mean chain lengths (or chain lengths) of a sample (alkanes or mixtures of alkanes) and therefore the constituents of the sample.

Abstract: The present invention is a method for modifying any synthetically generated assay of a whole crude oil or a portion of a whole crude, such as a condensate or resid material, by using measured crude properties. These measured properties are used to adjust the synthesized assay values to obtain a more accurate representation of the unknown hydrocarbon material.

Abstract: A method and system for evaluating status and response of a mineral-producing field (e.g., oil and/or gas) by monitoring selected chemical and physical properties in or adjacent to a wellsite headspace. Nanotechnology sensors and other sensors are provided for one or more underground (fluid) mineral-producing wellsites to determine presence/absence of each of two or more target molecules in the fluid, relative humidity, temperature and/or fluid pressure adjacent to the wellsite and flow direction and flow velocity for the fluid. A nanosensor measures an electrical parameter value and estimates a corresponding environmental parameter value, such as water content or hydrocarbon content. The system is small enough to be located down-hole in each mineral-producing horizon for the wellsite.

Abstract: In at least one embodiment, the inventive technology relates to in-vessel generation of a material from a solution of interest as part of a processing and/or analysis operation. Preferred embodiments of the in-vessel material generation (e.g., in-vessel solid material generation) include precipitation; in certain embodiments, analysis and/or processing of the solution of interest may include dissolution of the material, perhaps as part of a successive dissolution protocol using solvents of increasing ability to dissolve. Applications include, but are by no means limited to estimation of a coking onset and solution (e.g., oil) fractionating.

Abstract: A method for marking a petroleum hydrocarbon, a biodiesel fuel or an ethanol fuel, by adding an organic marker compound.

Abstract: Non-cementitious CO2 sequestering compositions are provided. The compositions of the invention include a CO2 sequestering additive, e.g., a CO2 sequestering carbonate composition. Additional aspects of the invention include methods of making and using the non-cementitious CO2 sequestering compositions.

Abstract: A method is disclosed for predicting the High Frequency Reciprocating Rig (HFRR) wear scar diameter for a hydrocarbon mixture using an HFRR wear scar diameter prediction equation which predicts the HFRR wear scar diameter based on the mid-infrared spectroscopy test results for such hydrocarbon mixture. Such predicted HFRR wear scar diameter value can then be used to determine the necessity of adding a lubricity additive to a diesel material in order to produce a diesel product possessing adequate lubricity properties.

Abstract: The invention relates to a method allowing to determine at least one petroleum characteristic of a geologic sediment sample, wherein the sample is heated in an oxidizing atmosphere, its temperature being successively raised to a first, then to a second value, said first value below 200° C. being reached very quickly, then maintained substantially constant for a certain time, said second value ranging between 600° C. and 850° C. being reached with a temperature gradient ranging between 1 and 30° C./min, from said first value. According to the invention, the amount of SO2 contained by the effluent resulting from said oxidizing heating is measured continuously, every moment of the heating period of said sample.

Abstract: A method for quantifying the presence of naphthenic acids in a hydrocarbon-comprising liquid that includes: contacting a hydrocarbon-comprising liquid with gaseous ammonia; isolating a reaction product produced by the contacting step; and analyzing the reaction product for the presence of naphthenates using a mass spectrometry technique. The naphthenic acids known to form commercial naphthenate deposits can be (i) ions of tetraprotic carboxylic acids having molecular weights ranging from 1225 to 1270 Daltons, (ii) n-alkyl or branched carboxylic acids having molecular weights ranging from 250 to 650 Daltons, or (iii) both.

Abstract: A system for determining parameters and compatibility of a substance such as an asphalt or other petroleum substance uses titration to highly accurately determine one or more flocculation occurrences and is especially applicable to the determination or use of Heithaus parameters and optimal mixing of various asphalt stocks. In a preferred embodiment, automated titration in an oxygen gas exclusive system and further using spectrophotometric analysis (2-8) of solution turbidity is presented. A reversible titration technique enabling in-situ titration measurement of various solution concentrations is also presented.

Abstract: The diffusion coefficients and relaxation times of mixtures of alkanes follow simple scaling laws based on the chain length of the constituents and the mean chain length of the mixture. These scaling laws are used to determine chain sizes in a mixture from the distribution of the diffusion coefficients. These scaling laws can be used to determine the mean chain lengths (or chain lengths) of a sample (alkanes or mixtures of alkanes) and therefore the constituents of the sample.

Abstract: Methods and related systems for fabricating a device or a part, the method including the step of growing at least one material from a vapor phase, by a CVD process, for example a MO-CVD process, on a heated base substrate, wherein the at least one material conforms to one of at least one topographical pattern of the base substrate, one or more predefined geometrical shape on the base substrate or both. The method includes removing the base substrate embedded in the CVD deposited material, as well as optionally machining a portion of the CVD deposited material.

Abstract: A method for blending at least two hydrocarbon liquids, the method comprising: (a) determining the critical solvent power for each hydrocarbon liquid by (i) mixing each hydrocarbon liquid with predetermined amounts of a paraffin; (ii) centrifuging each resulting mixture; (iii) recovering and weighing any resulting precipitated insolubles from step (ii); and (iv) correlating the weight of the insolubles in step (iii) to the solvent power at which asphaltenes begin to precipitate out of the hydrocarbon; (b) determining the solvent power for each hydrocarbon liquid by: (i) determining the distillation curve and density of each hydrocarbon liquid; (ii) numerically integrating the distillation curve of each hydrocarbon liquid, producing the volume average boiling point for each hydrocarbon liquid; (iii) calculating the characterization K factor for each hydrocarbon liquid using the volume average boiling point in step (ii); and (iv) determining the solvent power of each hydrocarbon liquid using the characterizatio

Abstract: A tagged object includes a main body and a plurality of coded particles. Each coded particle may have a miniature body and be configured to provide a resolvable optical emission pattern when illuminate. The plurality of coded particles may be immobilized to the main body. A method for performing oilfield monitoring may include disposing of different types of tagged objects at different locations, wherein the different types of tagged objects each comprise a plurality of coded particles. Each of the coded particles may have a miniature body containing rare earth elements configured to produce a unique optical emission pattern when illuminated. The method may include allowing an event to trigger the release of one of the different types of tagged objects from one of the different locations. In addition, the method may include identifying the released tagged objects by unique optical emission patterns, in some cases in order to determining an occurrence location of the event.

Abstract: A method and apparatus is described for estimating terminal purity or terminal contamination for a fluid during the withdrawal of the fluid from a subsurface formation. The apparatus and method provide for measuring refractive index of the fluid over a time period, fitting a curve through the refractive index measurements or data values derived therefrom and estimating a terminal refractive index or terminal value for the data values from the fitted to curve to estimate the terminal contamination or purity for the fluid.

Abstract: The present invention is directed to novel assays for zero-valent transition metals. The novel assays of the present invention are generally methods or processes for quantitatively and/or qualitatively evaluating the presence of zero-valent transition metals on and/or within samples. Such assays generally involve a digestion process whereby the sample is exposed to carbon monoxide. Transition metals, if present in or on the sample and if contacted by the carbon monoxide, are extracted by the carbon monoxide as metal carbonyl species, the presence of which confirms the presence of transition metals. Such novel assays have enormous predictive power in oil and gas exploration.

Abstract: The present invention provides a method and apparatus or system for determining an amount of coal tar that can enter, and subsequently be displaced from, a given type of soil for a range of depths of the soil. The method and apparatus also provide verification of the pressure at which coal tar can be displaced from a given type of soil. In particular, the method and apparatus simulate the hydrostatic pressure that a soil sample encounters in the subsurface of the ground. Accordingly, the method and apparatus provide a relationship between the concentration of coal tar in the soil and the pressure required to displace the coal tar from the soil, which allows for an estimation of the amount of coal tar that may be displaced at a particular location or site. Further, the method and apparatus are adaptable for use in the laboratory or the field.