Abstract: A technique utilizes spatially resolved temperature measurements to infer the temperature of a subsea infrastructure. According to an embodiment, temperature data, e.g. a temperature map, is determined for the subsea infrastructure and comprises performing remote temperature measurements of water surrounding the subsea infrastructure. Additionally, a metrological scan of the subsea structure may be obtained. Furthermore, a simulation or simulations may be run for an assumed temperature profile along a surface of the subsea infrastructure. The data obtained from the remote temperature measurements, the metrological scan, and the simulation is processed to determine a temperature profile of the subsea infrastructure. This temperature profile can then be used to facilitate a variety of subsea infrastructure management decisions.

Abstract: A technique utilizes spatially resolved temperature measurements to infer the temperature of a subsea infrastructure. According to an embodiment, temperature data, e.g. a temperature map, is determined for the subsea infrastructure and comprises performing remote temperature measurements of water surrounding the subsea infrastructure. Additionally, a metrological scan of the subsea structure may be obtained. Furthermore, a simulation or simulations may be run for an assumed temperature profile along a surface of the subsea infrastructure. The data obtained from the remote temperature measurements, the metrological scan, and the simulation is processed to determine a temperature profile of the subsea infrastructure. This temperature profile can then be used to facilitate a variety of subsea infrastructure management decisions.

Abstract: Methods may include emplacing a wellbore tool in a wellbore, the wellbore tool including a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr, measuring a sample from the wellbore using the wellbore tool, and determining a molecular weight of one or more components of the sample from the measured response of the wellbore tool. Methods may also include establishing a library of one or more chemical components, emplacing a wellbore tool in a wellbore, the wellbore tool including a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr, measuring a sample from the wellbore using the wellbore tool, comparing the measured response from the wellbore tool for the sample with results from the library of one or more chemical components, and determining a molecular weight of one or more components of the sample.

Abstract: Apparatus and method for Raman-spectrography based measurement of the composition of gas mixture in a high-temperature borehole. The method includes any of determining molar densities of individual alkanes of the mixture, introducing refractive index corrections, utilization of reference species internally to the measurement apparatus, correction for the effect of self-absorption and cross-absorption, as well as minimizing fluorescence when a liquid fraction is present in the borehole. The apparatus is configured to detect vibrational bands of CH, OH, CC, HS, NN and CO functional groups as well as collective modes in the fingerprint spectral region.

Abstract: Apparatus and method for Raman-spectrography-based measurement of the composition of gas mixture in a high-temperature borehole. The method includes any of determining molar densities of individual alkanes of the mixture, introducing refractive index corrections, utilization of reference species internally to the measurement apparatus, correction for the effect of self-absorption and cross-absorption, as well as minimizing fluorescence when a liquid fraction is present in the borehole. The apparatus is configured to detect vibrational bands of CH, OH, CC, HS, NN and CO functional groups as well as collective modes in the fingerprint spectral region.

Abstract: Solid state lasers are disclosed herein. An example laser disclosed herein includes a monolithic body having a first end and a second end. The monolithic body includes a first reflector disposed on the first end, a second reflector disposed on the second end, and a solid state gain medium and a Q-switch disposed between the first reflector and the second reflector. The example laser also includes a pump source to cause a population inversion in the solid state gain medium to cause the monolithic body to output a laser pulse. Various applications of the solid state laser are also disclosed herein.

Abstract: A downhole tool is conveyed within a borehole extending into a subterranean formation. Fluid is drawn from the subterranean formation into the downhole tool, wherein the fluid comprises heavy oil. Fluorescence intensity of the drawn fluid is measured via a sensor of the downhole tool, and asphaltene content of the drawn fluid is estimated based on the measured fluorescence intensity.

Abstract: Wellbore tools in accordance with the present disclosure may include a gas chromatograph; and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr. Systems in accordance with the present disclosure may include a gas chromatograph; and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr. Methods in accordance with the present disclosure may include emplacing a wellbore tool in a wellbore, the wellbore tool containing a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr; drawing a sample of a fluid from the wellbore into the wellbore tool; and determining a molecular weight of one or more components of the fluid.

Abstract: Methods may include emplacing a wellbore tool in a wellbore, the wellbore tool including a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr, measuring a sample from the wellbore using the wellbore tool, and determining a molecular weight of one or more components of the sample from the measured response of the wellbore tool. Methods may also include establishing a library of one or more chemical components, emplacing a wellbore tool in a wellbore, the wellbore tool including a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr, measuring a sample from the wellbore using the wellbore tool, comparing the measured response from the wellbore tool for the sample with results from the library of one or more chemical components, and determining a molecular weight of one or more components of the sample.

Abstract: Wellbore tools in accordance with the present disclosure may include a gas chromatograph; and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr. Systems in accordance with the present disclosure may include a gas chromatograph; and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr. Methods in accordance with the present disclosure may include emplacing a wellbore tool in a wellbore, the wellbore tool containing a gas chromatograph and a mass spectrometer, wherein the mass spectrometer is configured to operate at a pressure greater than 10?2 Torr; drawing a sample of a fluid from the wellbore into the wellbore tool; and determining a molecular weight of one or more components of the fluid.

Abstract: A formation fluid sample is analyzed using NMR spectroscopy to obtain a NMR spectrum. The NMR spectrum is then analyzed to find evidence of the amount of olefins present in the sample. The amount of olefins present in the sample can then be correlated to the level of contamination of the sample. In one embodiment, a 1H chemical shift of between substantially 4.5 and 6 ppm is used to identify olefins present in the sample. In another embodiment, a 1H chemical shift of substantially 1.9 to 2.1 ppm is used to identify olefins present in the sample. The NMR spectral equipment can be located uphole or downhole.

Abstract: Apparatus and method for Raman-spectrography-based measurement of the composition of gas mixture in a high-temperature borehole. The method includes any of determining molar densities of individual alkanes of the mixture, introducing refractive index corrections, utilization of reference species internally to the measurement apparatus, correction for the effect of self-absorption and cross-absorption, as well as minimizing fluorescence when a liquid fraction is present in the borehole. The apparatus is configured to detect vibrational bands of CH, OH, CC, HS, NN and CO functional groups as well as collective modes in the fingerprint spectral region.

Abstract: A method of analyzing physical properties of a sample includes obtaining the sample and obtaining an electromagnetic spectrum of the sample using terahertz spectroscopy. A sample complex permittivity is computed from the electromagnetic spectrum of the sample. The method further includes estimating the constituents and the constituent fractions and computing an estimated effective complex permittivity based upon a model and the constituent fractions. The method further includes comparing the computed sample complex permittivity with the estimated effective complex permittivity in order to determine the physical properties the sample.

Abstract: A methodology for reservoir understanding employs analysis of fluid property gradients to investigate and distinguish between non-compartmentalization of the reservoir, compartmentalization of the reservoir, and lack of thermodynamic equilibrium in the reservoir.

Abstract: A production logging tool (PLT) is conveyed within production tubing containing production fluid flow established by zonal fluid flow from formation zones. The PLT measures a flow rate of the production fluid flow at each of a plurality of depths associated with a corresponding one of the zones. A flow rate of the zonal fluid flow from each zone is determined based on the flow rates of the production fluid flow measured at each of the depths. The PLT measures proportions of compositional components of the production fluid flow at each of the depths. A flow rate of each compositional component of the zonal fluid flow from each zone is determined based on the determined flow rate of the zonal fluid flow from each zone and the proportions of compositional components of the production fluid flow measured at each of the depths.

Abstract: A formation fluid sample is analyzed using NMR spectroscopy to obtain a NMR spectrum. The NMR spectrum is then analyzed to find evidence of the amount of olefins present in the sample. The amount of olefins present in the sample can then be correlated to the level of contamination of the sample. In one embodiment, a 1H chemical shift of between substantially 4.5 and 6 ppm is used to identify olefins present in the sample. In another embodiment, a 1H chemical shift of substantially 1.9 to 2.1 ppm is used to identify olefins present in the sample. The NMR spectral equipment can be located uphole or downhole.

Abstract: A method of analyzing physical properties of a sample includes obtaining the sample and obtaining an electromagnetic spectrum of the sample using terahertz spectroscopy. A sample complex permittivity is computed from the electromagnetic spectrum of the sample. The method further includes estimating the constituents and the constituent fractions and computing an estimated effective complex permittivity based upon a model and the constituent fractions. The method further includes comparing the computed sample complex permittivity with the estimated effective complex permittivity in order to determine the physical properties the sample.

Abstract: A production logging tool (PLT) is conveyed within production tubing containing production fluid flow established by zonal fluid flow from formation zones. The PLT measures a flow rate of the production fluid flow at each of a plurality of depths associated with a corresponding one of the zones. A flow rate of the zonal fluid flow from each zone is determined based on the flow rates of the production fluid flow measured at each of the depths. The PLT measures proportions of compositional components of the production fluid flow at each of the depths. A flow rate of each compositional component of the zonal fluid flow from each zone is determined based on the determined flow rate of the zonal fluid flow from each zone and the proportions of compositional components of the production fluid flow measured at each of the depths.

Abstract: A downhole tool is conveyed within a borehole extending into a subterranean formation. Fluid is drawn from the subterranean formation into the downhole tool, wherein the fluid comprises heavy oil. Fluorescence intensity of the drawn fluid is measured via a sensor of the downhole tool, and asphaltene content of the drawn fluid is estimated based on the measured fluorescence intensity.

Abstract: Solid state lasers are disclosed herein. An example laser disclosed herein includes a monolithic body having a first end and a second end. The monolithic body includes a first reflector disposed on the first end, a second reflector disposed on the second end, and a solid state gain medium and a Q-switch disposed between the first reflector and the second reflector. The example laser also includes a pump source to cause a population inversion in the solid state gain medium to cause the monolithic body to output a laser pulse. Various applications of the solid state laser are also disclosed herein.