Abstract: A computer receives a measured wetness of and a measured ?2H value associated with a test gas sample from a hydrocarbon formation. The measured wetness is a molar ratio of heavy gas compounds over a total gas within the measured sample. The computer receives calculated wetnesses calculated ?2H values associated with a gas samples taken from one or more analogous hydrocarbon reservoirs. The measured wetness received for the test gas sample is identified from among the plurality of calculated wetnesses. The computer determines a corresponding ?2H value from among the calculated ?2H values that corresponds to the measured wetness of the test gas sample. The computer determines a predicted sample VRo (vitrinite reflectance equivalent) for the test gas sample based on the corresponding ?2H value and a correlation of ?2H values to VRo values. Hydrocarbons are produced from the hydrocarbon formation based on the predicted sample VRo.

Abstract: Embodiments may include a hydrogen sulfide scrubber system that includes a charging chamber, a reaction vessel, and a treated gas trap. Embodiments may include a mobile vehicle, vessel, or platform that includes a mobile vehicle, vessel, or platform with a mounted hydrogen sulfide scrubber system. The hydrogen sulfide scrubber system is configured as previously described. Embodiments may include a method of using a hydrogen sulfide scrubber system.

Abstract: A computer receives a measured wetness of and a measured ?2H value associated with a test gas sample from a hydrocarbon formation. The measured wetness is a molar ratio of heavy gas compounds over a total gas within the measured sample. The computer receives calculated wetnesses calculated ?2H values associated with a gas samples taken from one or more analogous hydrocarbon reservoirs. The measured wetness received for the test gas sample is identified from among the plurality of calculated wetnesses. The computer determines a corresponding ?2H value from among the calculated ?2H values that corresponds to the measured wetness of the test gas sample. The computer determines a predicted sample VRo (vitrinite reflectance equivalent) for the test gas sample based on the corresponding ?2H value and a correlation of ?2H values to VRo values. Hydrocarbons are produced from the hydrocarbon formation based on the predicted sample VRo.

Abstract: A computer receives a measured wetness of and a measured ?2H value associated with a test gas sample from a hydrocarbon formation. The measured wetness is a molar ratio of heavy gas compounds over a total gas within the measured sample. The computer receives calculated wetnesses calculated ?2H values associated with a gas samples taken from one or more analogous hydrocarbon reservoirs. The measured wetness received for the test gas sample is identified from among the plurality of calculated wetnesses. The computer determines a corresponding ?2H value from among the calculated ?2H values that corresponds to the measured wetness of the test gas sample. The computer determines a predicted sample VRo (vitrinite reflectance equivalent) for the test gas sample based on the corresponding ?2H value and a correlation of ?2H values to VRo values. Hydrocarbons are produced from the hydrocarbon formation based on the predicted sample VRo.

Abstract: A method of fabricating and utilizing an unconventional reservoir maturity chart is provided. A historical dataset for a Paleozoic or a pre-Paleozoic shale or sandstone unconventional reservoir is utilized to obtain carbon isotopic ratio values for ?13C1, ?13C2, and vitrinite reflectance equivalents (VRE). Such data is utilized to plot several maturity shapes based upon VRE values, where several of the maturity shapes have a maturity shape boundary defined by the relationship ?13C1=?13C2. The method for utilizing the unconventional reservoir maturity chart may include determining a maturity level for the hydrocarbon gas sample based upon a relative position of the plotted data point versus a first maturity shape, a second maturity shape, a third maturity shape, and a fourth maturity shape. The method may also permit determining a production plan for the unconventional reservoir associated with the hydrocarbon gas sample.

Abstract: Embodiments may include a hydrogen sulfide scrubber system that includes a charging chamber, a reaction vessel, and a treated gas trap. Embodiments may include a mobile vehicle, vessel, or platform that includes a mobile vehicle, vessel, or platform with a mounted hydrogen sulfide scrubber system. The hydrogen sulfide scrubber system is configured as previously described. Embodiments may include a method of using a hydrogen sulfide scrubber system.

Abstract: A core sample with carbonate veins is obtained from a well formed in the hydrocarbon reservoir. Formation water samples are obtained from the well. Mineralogy of carbonate in the carbonate veins is analyzed. An oxygen isotope ratio between oxygen isotopes in the formation water and an oxygen isotope ratio between oxygen isotopes in the carbonates are determined. A formation paleo-temperature value is determined based on the determined oxygen isotope ratio using a model that relates the formation paleo-temperature value and the oxygen isotope ratio.

Abstract: Carbonate samples are received from a wellbore formed in a geologic formation. An oxygen isotope ratio and carbon isotope ratio present within each of the carbonate samples are determined. A mineral composition of each of the carbonate samples is determined. A plot showing the determined oxygen isotope ratios versus a depth from where within the wellbore each of the carbonate samples was obtained is created. One or more negative oxygen isotope shifts are identified based on the plot. Natural carbonate cement levels within one or more of the plurality of carbonate samples that correspond to the one or more negative oxygen isotope shifts identified in the plot are determined. One or more production sweet spots are determined based on the identified negative oxygen isotope shifts and the determined natural carbonate cement levels.

Abstract: A measured wetness of and a ?13C associated with a gas sample from a hydrocarbon formation is received wherein the wetness is a percentage of C2+ by mass. Calculated wetnesses of and ?13C values associated with a plurality of gas samples taken from one or more analogous hydrocarbon reservoirs is received. Each wetness is calculated as a percentage of mass within the gas sample. The measured wetness received for the gas sample from among the calculated wetnesses is identified. A ?13C is determined from among the ?13C values that corresponds to the measured wetness of the gas sample. A gas maturity for the gas sample is determined using the determined ?13C.

Abstract: A measured wetness of and a carbon isotope ratio associated with a gas sample from a hydrocarbon formation is received wherein the wetness is a percentage of C2+ by mass. The carbon isotope ratio is a ratio of carbon-13 isotopes over carbon-12 isotopes. Calculated wetnesses of and carbon isotope ratios associated with a plurality of gas samples taken from one or more analogous hydrocarbon reservoirs is received. Each wetness is calculated as a percentage of mass within the gas sample. The measured wetness received for the gas sample from among the calculated wetnesses is identified. A carbon isotope ratio is determined from among the carbon isotope ratios that corresponds to the measured wetness of the gas sample. A gas maturity for the gas sample is determined using the determined carbon isotope ratio.

Abstract: Carbonate samples are received from a wellbore formed in a geologic formation. An oxygen isotope ratio and carbon isotope ratio present within each of the carbonate samples are determined. A mineral composition of each of the carbonate samples is determined. A plot showing the determined oxygen isotope ratios versus a depth from where within the wellbore each of the carbonate samples was obtained is created. One or more negative oxygen isotope shifts are identified based on the plot. Natural carbonate cement levels within one or more of the plurality of carbonate samples that correspond to the one or more negative oxygen isotope shifts identified in the plot are determined. One or more production sweet spots are determined based on the identified negative oxygen isotope shifts and the determined natural carbonate cement levels.

Abstract: A core sample with carbonate veins is obtained from a well formed in the hydrocarbon reservoir. Formation water samples are obtained from the well. Mineralogy of carbonate in the carbonate veins is analyzed. An oxygen isotope ratio between oxygen isotopes in the formation water and an oxygen isotope ratio between oxygen isotopes in the carbonates are determined. A formation paleo-temperature value is determined based on the determined oxygen isotope ratio using a model that relates the formation paleo-temperature value and the oxygen isotope ratio.