Abstract: The present invention relates to a method and system for quantitatively evaluating surface roughness of an organic pore of kerogen in shale. The method includes: making a shale sample; applying a circle of silver-painted conductive tape on the edge of the shale sample to obtain a processed sample; conducting image scanning on the processed sample to obtain a scanned image; determining a kerogen area according to the scanned image; determining an organic pore area according to the kerogen area; carrying out gridding treatment on the organic pore area to obtain multiple grid cells; adopting double integral calculation on each of the grid cells to obtain the areas of the multiple grid cells; summing each of the areas to obtain the surface area of the organic pore; and evaluating surface roughness of the organic pore according to the surface area of the pore.

Abstract: A method and system for identifying a fluid sample. The method may comprise disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a wellbore fluid as a fluid sample through the at least one probe and through the at least one passageway, obtaining a fluid measurement of the fluid sample, comparing the fluid measurement to a plurality of fingerprints that populate a database, and identifying the fluid sample based at least in part on one of the plurality of fingerprints.

Abstract: Method of monitoring produced water at each perforation or entry point by real time ion sensor deployed downhole to measure the content of water soluble ions. Methods of determining and differentiating nature of water breakthrough in oil production; such as between cycled injection water through a void space conduit, matrix swept injection water and formation water, especially as relates to offshore oil production. Real time ion sensors are deployed and when compared with known standards are used to monitor and remediate water breakthrough, prevent scale deposition, and the like.

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 radioactive fine particle manufacturing system and method to manufacture physically stable radioactive fine particles, and which enables performance evaluation of a radioactivity measuring instrument employing a physical indicator, by controlling radioactivity concentration, and facilitating performance evaluation of the overall radioactivity measuring instrument. The radioactive fine particle manufacturing system includes a radioactive gas generating system, a specific particle-sized aerosol generating system and a mixing chamber, to manufacture radioactive fine particles employing natural radioactive nuclides, and uses. 220Rn to manufacture radioactive fine particles using physically stable progeny nuclides. In the mixing chamber, the progeny nuclides are caused to attach only to an aerosol having a specific particle size, to generate radioactive fine particles having a specific particle size.

Abstract: A system, method, and apparatus for real-time characterization of drilled particles during a drilling operation can be comprised of a light illumination source to output short-wave-infrared (SWIR) light toward the drilled particles as the drilled particles exit a drill hole being drilled by a drilling machine; a sensor to sense reflected short-wave-infrared (SWIR) light reflected from the drilled particles exiting the drill hole; and processing circuitry operatively coupled to at least the sensor. The processing circuitry can be configured to determine a spectrum of the reflected short-wave-infrared light sensed by the sensor, and determine particle characterization for a portion of the drilled particles by performing hyperspectral analysis on the determined spectrum and based on predetermined candidate particle characterizations.

Abstract: A system can identify a type of contamination for drilling fluid based on measured fluid properties of the drilling fluid and fluid properties of a reference drilling fluid. A system can measure a first plurality of fluid properties for a drilling fluid sample contaminated from a wellbore drilling operation. A system can select a predicted model in relation to one or more types of contamination by comparing the first plurality of fluid properties and a second plurality of fluid properties measured from a reference fluid sample. A system can analyze the first plurality of fluid properties and a third plurality of fluid properties generated from the predicted model to determine a first type of contamination in the drilling fluid sample.

Abstract: Methods, systems, devices, and products for well logging. Methods include conveying a logging tool in the borehole on a carrier; obtaining a borehole image over at least one interval of borehole depth from well logging measurements with a downhole imaging instrument; obtaining acoustic information representative of acoustic reflections from a far-field region of the formation; obtaining quantitative borehole fluid information indicative of properties of a formation fluid in a near-field region of the borehole; generating a borehole connectivity fracture model of the formation in dependence upon the borehole image, the quantitative borehole fluid information, and the acoustic information. Methods may include identifying near-field fractures from the borehole image, and/or identifying far-field fractures from the acoustic information.

Abstract: A system and method for characterizing matter, for example, soil organic content is disclosed. A radiation and electric field sensor measure sample properties before, during and after irradiation. Calibrations are developed relating those measurements to useful properties of matter, for example, soil density and organic content. As an example of an embodiment of the disclosed invention an instrument attachment for portable X-ray fluorescence instrumentation was prototyped enabling concurrent volumetric soil organic matter quantification. This primary prototype outperformed more expensive emerging visible-near infrared multivariate instrumentation using parsimonious soil specific simple linear regression (R2 ranged 0.85-0.97) enabling rapid, parallel, nondestructive, cost-effective acquisition of soil elemental concentrations together with organic content data.

Abstract: A method may include transforming optical responses for a fluid sample to a parameter space of a downhole tool. The optical responses are obtained using a first operational sensor and a second operational sensor of the downhole tool. Fluid models are applied in the parameter space of the downhole tool to the transformed optical responses to obtain density predictions of the fluid sample. The density predictions of the first operational sensor are matched to the density predictions of the second operational sensor based on optical parameters of the fluid models to obtain matched density predictions. A difference between the matched density predictions and measurements obtained from a densitometer is calculated, and a contamination index is estimated based on the difference.

Abstract: A method and device construction for detecting of hiding places with smuggled materials in the extremely heavy railway loads transporting iron ore by the means of neutron beam are disclosed. Upon the scanning of the iron ore load with neutrons the searched cavities or leaden containers with contraband are expressed by reducing of the flow of passing neutrons. The outline width of the scanned load is measured by dimension detectors. Values of differences between the scanned widths of the load and the outline widths are measures of the cavity dimensions with smuggled materials and said measures are included into the neutron radiographic image.

Abstract: The present invention provides techniques for recovering hydrocarbon fluids in a process flow, including recovering bitumen from a coarse tailings line. The apparatus includes a signal processor that responds to signaling containing information about the presence of a hydrocarbon fluid in a process flow; and determines corresponding signaling to control the diversion of the hydrocarbon fluid from the process flow remaining based on the signaling received. The hydrocarbon fluid may be bitumen, including bitumen flowing in a course tailings line. The signal processor receives the signaling from a velocity profile meter having sensors arranged around a circumference of a process pipe containing information about a fluid flow velocity at various levels or heights within the process pipe, including a wrap-around velocity profile meter having multiple sensing arrays located radially at a top position of 0°, a bottom position of 180°, and intermediate positions 45°, 90° and 135°.

Abstract: A method for depth determination of drilled rock cuttings is disclosed. The taggant is injected and transported downhole along the mud stream and attaches to the rock cuttings. Taggant impregnated cuttings are detected at the surface based on molecular weight, emission wavelengths or radio frequency characteristics for encoding the taggant. The identification code identifies the depth of the drill bit when the particular batch of the taggant is released into the mud. The detection data, in addition to mud properties, flow rates, drill volume and penetration rates, formation characteristics, and well specifications are transferred to and analyzed by a taggant analysis and control engine. The taggant analysis and control engine controls an IoT controller that adapts the parameters of the taggant injection pump to achieve an intelligent controlled release to optimize the depth characterization process.

Abstract: A method for soil moisture retrieval using multi-channel collaboration algorithm and passive microwave radiometry including: establishing mathematical relationship formula between brightness temperatures at any two channels according to microwave radiative transfer equation; collecting actual brightness temperatures of core channel and collaborative channels; selecting parameters to be retrieved including soil moisture value; giving a series of estimated values of parameters to be retrieved, calculating a series of predicted brightness temperatures of collaborative channels according to actual brightness temperature of core channel, microwave radiative transfer equation and mathematical relationship formula, comparing predicted brightness temperatures with actual brightness temperature, and determining soil moisture value.

Abstract: Aspects of the subject technology relate to systems and methods for identifying values of mud and formation parameters based on measurements gathered by an electromagnetic imager tool through machine learning. One or more regression functions that model mud and formation parameters capable of being identified through an electromagnetic imager tool as a function of possible tool measurements of the electromagnetic imager tool can be generated using a known dataset associated with the electromagnetic imager tool. One or more tool measurements obtained by the electromagnetic imager tool operating to log a wellbore can be gathered. As follows, one or more values of the mud and formation parameters can be identified by applying the one or more regression functions to the one or more tool measurements.

Abstract: Methods, apparatus, systems and articles of manufacture are disclosed relating to drones. An example drone includes a payload receiving area to receive a container, a payload retainer to secure the container relative to the payload receiving area, and a spectrometer positioned relative to the payload receiving area to measure a first spectrum of a payload within the container.

Abstract: Disclosed are methods and systems for determination of fluid contamination of a fluid sample from a downhole fluid sampling tool. A method may comprise obtaining a fluid sample, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid; obtaining input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample and mud filtrate composition; obtaining initial values of iterative parameters, wherein the iterative parameters comprise fluid contamination of the fluid sample; determining calculated fluid properties of the reservoir fluid using equation of state flash calculating; and repeating steps of determining component mole fractions and determining calculated fluid properties for use in the mole fraction distribution function until a comparison of one or more of the calculated fluid properties with one or more of the input parameters is within a tolerance error.

Abstract: A system and method for identifying a probability of disease affecting a crop based on data received over a network is described herein, and may be implemented using computers for providing improvements in plant pathology, plant pest control, agriculture, or agricultural management. In an embodiment, a server computer receives environmental risk data, crop data, and crop management data relating to one or more crops on a field. Agricultural intelligence computer system 130 computes one or more crop risk factors based, at least in part, the crop data, one or more environmental risk factors based, at least in part, the environmental data, and one or more crop management risk factors based, at least in part, on the crop management data.

Abstract: Embodiments are disclosed for terahertz spectroscopy and imaging in dynamic environments. In an embodiment, a method comprises emitting a continuous electromagnetic (EM) wave in a terahertz (THz) frequency band into a dynamic environment. The EM THz wave is reflected off an object in the environment. A spectral response of a received signal indicative of the reflected EM wave is determined that includes absorption spectra at a frequency in the THz frequency band. The absorption spectra is indicative of a transmission medium in the environment. The spectral response of the received signal is compensated for fixed and frequency-specific losses. The compensated absorption spectra is compared with known absorption spectra of target transmission mediums. Based on results of the comparing, a particular target transmission medium is identified as being the transmission medium in the environment. The absorption spectra loss is used to determine a concentration level of the target transmission medium.

Abstract: The ability to communicate with a specific subject at a prescribed location who lacks any communications equipment opens up many intriguing possibilities. Communications across noisy rooms, hail and warn applications, and localized communications directed at only the intended recipient are a few possibilities. We disclose and show localized acoustic communications, which we call photoacoustic communications, with a listener at long standoff distances using a modulated laser transmitted toward the receiver's ear. The optically encoded information is converted into acoustic messages via the photoacoustic effect. The photoacoustic conversion of the optical information into an audible signal occurs via the absorption of the light by ambient water vapor in the near area of the receiver's ear followed by airborne acoustic transmission to the ear. The recipient requires no external communications equipment to receive audible messages.

Abstract: Embodiments provide a method for evaluating a hydrocarbon-bearing formation. The method includes the step of identifying a hydrocarbon sweet spot. The identifying step includes determining a carbon dioxide content of a gas sample retrieved from the hydrocarbon-bearing formation. The identifying step includes determining an isotopic signature of carbon dioxide of the gas sample. The carbon dioxide content of the gas sample retrieved from the hydrocarbon sweet spot can have a mole percentage ranging from 9 percent to 20 percent. The isotopic signature of carbon dioxide of the gas sample retrieved from the hydrocarbon sweet spot can have a ?13C value greater than ?10 per mil. The identifying step can further include determining a cutoff range of the carbon dioxide content corresponding to the hydrocarbon sweet spot. The cutoff range can have a mole percentage ranging from 9 percent to 20 percent. The identifying step can further include obtaining a gas flow rate of the hydrocarbon-bearing formation.

Abstract: The purpose of the present invention is to provide a measurement method and a measurement device capable of accurately measuring various metal concentrations of metals included in a solution to be measured containing a plurality of additives and metals.

Abstract: Disclosed is a radiation measuring device capable of measuring concentration of radiation contained in indoor air. The radiation measuring device according to the present invention includes: an ionization chamber configured to be supplied with a voltage and to form a space for ionizing air introduced; a substrate assembly coupled to the ionization chamber and transfer the voltage supplied from the outside to the ionization chamber; a probe member provided in the ionization chamber and configured to detect an electric charge in the ionization chamber; and a switching element connected to the probe member and configured to allow a current to flow when the electric charge is applied to the probe member.

Abstract: Disclosed is a less expensive, more efficient process for enhanced oil recovery, particularly useful in high cost environments such as offshore. This process is known as single well gas assisted gravity drainage (SW-GAGD). The process comprises the steps of drilling from a single wellbore one or more horizontal laterals near the bottom of a payzone and injecting a fluid displacer such as nitrogen or carbon dioxide through injection points. The injectant sweeps the oil and other produced fluids in the reservoir towards other producing perforations in the single well.

Abstract: A photomicrograph of a rock sample is analyzed. One or more classification attributes of the photomicrograph are recorded. One or more maceral attributes of the photomicrograph are determined using automated face detection. Based on the one or more classification attributes and the one or more maceral attributes, one or more technical attributes of the photomicrograph are determined using automated face recognition. The one or more maceral attributes and the one or more technical attributes are provided.

Abstract: A method for deriving VOI for a hydrocarbon-bearing reservoir fluid model based on DFA data (“true fluid model”) versus an “incorrect fluid model” includes calculating first, second and third objective functions that are based on NPV(s) of simulated production by a reservoir simulator with different configurations. For the first objective function, the simulator is configured with the incorrect fluid model and control variables that are optimized to derive a first group of control variable values. For the second objective function, the simulator is configured with the true fluid model and the first group of control variable values. For the third objective function, the simulator is configured with the true fluid model and control variables that are optimized to identify a second group of control variable values. The objective functions can be deterministic, or can include statistics that account for uncertainty. A visualization of such results with uncertainty is also described.

Abstract: Methods and apparatus are provided for determining down-hole the composition of natural gas from a formation. Some methods include downhole measurements of the near-infrared spectra and the Joule-Thomson coefficient of the gas, and processing the results of the downhole measurements in order to obtain a determination of the amounts of a plurality of natural gas components such as CH4, C2H6, CO2, N2, and H2S.

Abstract: Aspects of a method for mapping a perforation tunnel and crush zone of a perforated core sample. The method may include scanning a perforated core sample having a perforation tunnel containing a permeability-impairing material with a first computerized tomography (CT) scanning apparatus to produce a first 3D model of the perforation tunnel. The method may further include forming a cleared perforation tunnel by removing at least a portion of the permeability-impairing material from within the perforation tunnel without splitting the core sample at the perforation tunnel, and scanning the perforated core sample having the cleared perforation tunnel with a second computerized tomography (CT) scanning apparatus to produce a second 3D model of the cleared perforation tunnel. The method may compare the first 3D model and the second 3D model to obtain a 3D mapping of the perforation tunnel or a crush zone.

Abstract: To acquire both excellent spectrum and sample image reflecting actual conditions of a sample, and to increase convenience of measurement, provided is a display device for a photometric analyzer, which is configured to irradiate a sample with light to analyze the sample, the display device being configured to display a measurement result of the photometric analyzer, and including: a controller; and a display, which is configured to display an image based on measurement data processed by the controller. The measurement data at least contains a spectrum indicating an intensity of emitted light, which is emitted by the sample irradiated with the light, and a sample image of the sample, which is taken by an imaging device. The display is configured to display the spectrum and the sample image in an arrangement in the same screen.

Abstract: A mud retort assembly includes a retort that heats a fluid and thereby generates vapors, a condenser in fluid communication with the retort to at least partially condense the vapors and thereby generate a liquid, a condensate collector that receives the liquid and residual vapors via an outlet pipe of the condenser, and a collector plug having a frustoconical body that extends partially into the condensate collector at an opening to the condensate collector. The collector plug defines a central aperture that receives the outlet pipe and has an annular flange extending radially outward from the frustoconical body to rest on the condensate collector at the opening.

Abstract: An optical measurement device includes a light source configured to output a terahertz wave and coaxial light having a wavelength different from the wavelength of the terahertz wave, coaxially with the terahertz wave; an intensity modulation unit configured to perform intensity modulation of at least the terahertz wave of the terahertz wave and the coaxial light in a predetermined modulation frequency; and a light detection unit configured to synchronously detects each of the terahertz wave and the coaxial light which have acted on a measurement subject via the intensity modulation unit based on the modulation frequency.

Abstract: Apparatus and methods for obtaining first properties of a fluid, such as by estimating a second property of the fluid based on the first properties using a machine learning algorithm, propagating a first uncertainty of the first properties to a second uncertainty of the second property, generating an expected phase envelope of the fluid based on the second property, and generating a deviation phase envelope of the fluid based on the second uncertainty.

Abstract: A system and method for detecting and quantifying proppant for optimized fracture treatment design in in-fill and new wells. Proppant is isolated from drilling fluids and then analyzed to determine whether a formation within the well has been properly stimulated based on the analysis. Placement of an in-fill well may be based upon the determination of whether the well has been properly stimulated.

Abstract: Borehole logging methods for estimating a parameter of interest using nuclear radiation. Methods include estimating a water saturation of the formation from gamma radiation from at least the formation detected in the borehole using a radiation detector, the gamma radiation responsive to a pulsed neutron source and resulting from at least one of: (i) decay of nitrogen-16 formed by activation of oxygen-16, and ii) inelastic scattering of neutrons from oxygen. This may include using at least one processor to: obtain a gamma ray count measurement, representing gamma rays from one of: (i) the decay of nitrogen-16 (ii) and the inelastic scattering, and estimate the water saturation using the gamma ray count measurement and a model comprising a relationship between measured gamma ray counts and modeled gamma ray counts from each of a fully water saturated formation and a minimally water saturated formation.

Abstract: Downhole tools for isolating and analyzing one or more gases include a gas separation assembly in fluid communication with a gas specific analyzer. The gas separation assembly includes a piston disposed within a housing and a separation volume defined between the piston and the housing. The piston is movable to separate a gas component and a liquid component from a downhole formation fluid within the separation volume. The gas specific analyzer is operable to measure one or more properties of the gas component. In some configurations, the gas specific analyzer is an optical assembly containing a light source, an optical detector, and a gas cell that contains an observation volume. The optical assembly is operable to measure one or more properties of the gas component within the observation volume via the light source and the optical detector.

Abstract: A hand-held synchronous scan spectrometer for in situ analysis of bacteria, viruses, and fungi includes a housing that contains a light source, a first monochromator positioned to receive light from the light source and operable to direct a wavelength of the light from the light source towards a sample, a second monochromator positioned to receive fluoresced light from the sample and light from first monochromator, and a detector disposed within the housing and positioned to receive light output from the second monochromator. The hand-held synchronous scan spectrometer can include a display that is integrated into the housing or can utilize a display of a removable display device (e.g., a cell phone, PDA, tablet, and the like).

Abstract: The invention relates to a system and to a method for measuring at least one flow property of at least one fluid in a porous medium. The measurement system (1) comprises at least one cell (2), means (7) for injecting fluid(s) into the cell and X-ray radiography means (4, 5).

Abstract: Disclosed is a less expensive, more efficient process for enhanced oil recovery, particularly useful in high cost environments such as offshore. This process is known as single well gas assisted gravity drainage (SW-GAGD). The process comprises the steps of drilling from a single wellbore one or more horizontal laterals near the bottom of a payzone and injecting a fluid displacer such as nitrogen or carbon dioxide through injection points. The injectant sweeps the oil and other produced fluids in the reservoir towards other producing perforations in the single well.

Abstract: Hydrocarbons concentrations are determined in drilling cuttings samples by generating a model for predicting hydrocarbons concentrations. Methods include dividing multiple samples removed from drilling fluid into two one set analyzed using a retort, and another set analyzed using a handheld NIR spectrometer to obtain NIR diffuse reflectance data. PLS analysis is used to correlate the retort data with the diffuse reflectance data to generate a calibration model. The model is validated with samples having unknown hydrocarbons concentration. The model is used to predict the hydrocarbons concentration for samples removed from drilling fluid taken from the rig site using the spectrometer to obtain diffuse reflectance data. During measurements, each sample contains 0.1 to 10 wt % moisture and each sample is in a clear container pressed against the spectrometer window such that the IR source from the handheld device can pass to the drilled solids sample within the clear container without opening the clear container.

Abstract: A method and apparatus for analyzing a bitumen-containing process stream and controlling a process. The method including directing a beam of infrared light at the bitumen-containing process stream, capturing light corresponding to the infrared light after interaction with the bitumen-containing process stream, and analyzing the captured light to obtain a spectrum. A composition estimate can be generated based on the spectrum and a calibrated model. A controller is operative to adjust a setpoint of the process in response to the composition estimate.

Abstract: Disclosed are methods and systems for determination of fluid contamination of a fluid sample from a downhole fluid sampling tool. A method may comprise obtaining a fluid sample, obtaining input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample and mud filtrate composition, obtaining initial values of iterative parameters, determining component mole fractions of the reservoir fluid using the initial values of the iterative parameters in a mole fraction distribution function, determining calculated fluid properties of the reservoir fluid using equation of state flash calculating, and repeating steps of determining component mole fractions and determining calculated fluid properties and further obtaining updated values of the iterative parameters for use in the mole fraction distribution function until a comparison of one or more of the calculated fluid properties with one or more of the input parameters is within a tolerance error.

Abstract: A photo acoustic non-destructive measurement apparatus and method for quantitatively measuring texture of a liquid. The apparatus includes a laser generating tool, an acoustic capturing device, and a data processing unit. The laser generating tool directs a laser towards a surface of a liquid contained in a container and creates pressure waves that propagate through the air and produce an acoustic signal. The acoustic capturing device records and forwards the signal to a data processing unit. The data processing unit further comprises a digital signal processing module that processes the received acoustic signal. A statistical processing module further filters the acoustic signal from the data processing unit and generates a quantitative acoustic model for texture attributes such as hardness and fracturability. The quantitative model is correlated with a qualitative texture measurement from a descriptive expert panel. Textures of liquids are quantitatively measured with the quantitative acoustic model.

Abstract: The present disclosure relates to methods and apparatus for determining a gas-oil ratio based on downhole fluid analysis measurements and calibrated gas-oil ratio parameters. According to certain embodiments, the parameters for calculating the gas-oil ratio may be calibrated using historical data from the reservoir. For example, previously determined gas-oil ratios may be employed to calibrate the parameters to the reservoir. The calibrated parameters may then be employed during sampling operations to determine the gas-oil ratio.

Abstract: A data system and a method for determining the harvestability and transportability of a stand marked for cutting, the method comprising: maintaining data on the properties of the soil of the stand; determining a value for the harvestability and transportability of the stand, which value is dependent on said properties; defining said value also on the basis of such conditions of said stand which affects said properties; maintaining data on the harvestability and transportability defined for the stand. Said property is one or more of the following: soil type, auxiliary attributes of the soil type, other permanent factors. Said conditions are one or more of the following: snow depth, frost depth, soil moisture content, temperature, amount of rainfall, quantity of growing stock, relations between tree species, other variable factors.

Abstract: Methods for determining the hardness and/or ductility of a material by compression of the material are provided as a first aspect of the invention. Typically, compression is performed on multiple sides of a geologic material sample in a contemporaneous manner. Devices and systems for performing such methods also are provided. These methods, devices, and systems can be combined with additional methods, devices, and systems of the invention that provide for the analysis of compounds contained in such samples, which can indicate the presence of valuable materials, such as petroleum-associated hydrocarbons. Alternatively, these additional methods, devices, and systems can also stand independently of the methods, devices, and systems for analyzing ductility and/or hardness of materials.

Abstract: A method of determining a property within a subterranean formation comprises introducing silica nanoparticles into a well; obtaining a sample of a fluid produced from the well; and analyzing the sample for presence of the silica nanoparticles, wherein the silica nanoparticles comprise a core, a donor chromophore, an acceptor chromophore, and an outer silica shell; the donor chromophore and the acceptor chromophore being selected such that an emission spectrum of the donor chromophore overlaps with an absorption spectrum of the acceptor chromophore.

Abstract: A downhole system includes a quartz enhanced photoacoustic spectrometer (QEPAS) configured to be positioned within a wellbore formed in a subterranean zone of a hydrocarbon formation, a sampling system coupled to the QEPAS, and a computer system connected to the QEPAS. The sampling system is configured to be positioned in the wellbore and obtain a sample of a wellbore fluid at a downhole location in the subterranean zone. The QEPAS is configured to spectroscopically scan the sample and to determine a plurality of quantities of a corresponding plurality of hydrocarbons in the same. The computer system includes one or more processors to perform operations including receiving the plurality of quantities of the plurality of hydrocarbons in the sample and determining a plurality of ratios, where each ratio is a ratio of one of the plurality of hydrocarbons with another of the plurality of hydrocarbons.

Abstract: A system and method is provided for enhancing hydrocarbon production. The method and system involve geochemistry analysis and include multiply substituted isotopolog and position specific isotope geochemistry. The method and system involve using clumped isotope and position specific isotope signatures to enhance monitoring of well and stimulation performance.

Abstract: Methods and systems use fluorescence to determine specific gravity of samples. A first light pulse is applied to a sample at a first angle-of-incidence. A second light pulse is applied to the sample at a second angle-of-incidence. A first ratio based on the intensity of a first fluorescence emission over a first time interval and the intensity of the first fluorescence emission over a second time interval is calculated. A second ratio based on the intensity of a second fluorescence emission over a third time interval and the intensity of the second fluorescence emission over a fourth time interval is calculated. An intensity ratio based on the first ratio and the second ratio is calculated. A specific gravity of the sample based on the intensity ratio is determined.

Abstract: A method is disclosed for producing hydrocarbons with the use of reservoir surveillance. The method includes interpreting a sample to determine noble gas signatures and clumped isotope signatures for the region of interest. Then, using the region of interest fingerprint to perform reservoir surveillance on produced fluids from the subsurface regions.