Abstract: A system includes a discharge tool positioned within a wellbore and configured to generate an electrical discharge that interacts with a rock formation proximate to the discharge tool, wherein the interaction of the electrical discharge with the rock formation vaporizes a portion of the rock formation to generate a discharge plasma. The system further includes an optical emission spectroscopy (OES) sub-system configured to determine an elemental composition of the portion of the rock formation based on optical emission generated by the discharge plasma, wherein at least a portion of the OES sub-system is positioned within the wellbore.

Abstract: A modular gas detection system includes a primary gas chromatograph, a constant volume extractor positionable to provide a continuous fluid sample to the primary gas chromatograph, and a total hydrocarbon analyzer. The modular gas detection system also includes a processing device and a memory device including instructions executable by the processing device for causing the processing device to perform operations. The operations include adjusting a detection scheme of the primary gas chromatograph to update a detection range for the continuous fluid sample to detect different hydrocarbons within a single column. Further, the operations include controlling routing of the continuous fluid sample from the constant volume extractor to the primary gas chromatograph and the total hydrocarbon analyzer.

Abstract: A system including an image acquisition unit in optical communication with a flow pathway. The system may include at least one illumination source directable toward a shale shaker. The illumination source may emit a light output. A band-stop filter may be affixed to the image acquisition unit to filter out infrared light. The band-stop filter may also allow electromagnetic radiation of the light output to reach the image acquisition unit. An analysis device may be used to determine a volume of downhole particles on the shale shaker using deflections of the light output observed by the image acquisition unit.

Abstract: A system can flush a drilling fluid sample with a hydrocarbon blend, which includes a determined concentration of at least one chemical species to generate a flushed drilling fluid sample. The system can extract a dissolved gas from the flushed drilling fluid sample. The system can determine a concentration over time of at least one chemical species of the dissolved gas. The system can generate an area per concentration curve based on the concentration over time of the at least one chemical species. The system can determine at least one concentration value of the at least one chemical species. The system can modify the at least one concentration value based on the area per concentration curve. The system can then correct bias caused by the gas extractor and fluid sampling system.

Abstract: Systems and methods are described for determining the lag time and origin of particles in entrained in a mud stream. A size and shape of the particles may be evaluated at the surface with a visual inspection system, which permits a settling rate to be determined for each of the particles in a non-Newtonian mud stream. Together with an analysis of the pumping schedule, mud properties, trajectory of the wellbore and other fluid dynamics associated with a wellbore operation, an origin of the each of the particles from within the wellbore may be determined. At least one operational parameter for the wellbore operation may be adjusted based on the determined origin of the particles. For example, a clean-out procedure may be initiated if it is determined that particles are settling in an undesirable location in the wellbore.

Abstract: Systems and methods of the present disclosure generally relate to reporting carbon and hydrogen isotopic ratios during a wellbore operation. A method for detecting isotopic ratios during the wellbore operation, comprises receiving a fluid sample from a wellbore during the wellbore operation; passing the fluid sample to an analytical instrument operable to determine isotopic ratios in the fluid sample; outputting data comprising isotopic ratios for at least carbon and hydrogen; assigning a depth to the data; and transmitting the data based on isotopic ratios encountered during the wellbore operation.

Abstract: Systems and methods of the present disclosure generally relate to correcting isotope ratio calculations during wellbore operation. A method for correcting isotope ratios during a wellbore operation, comprising receiving a flow-in fluid sample from a wellbore; receiving a flow-out fluid sample from the wellbore; passing each sample to an analytical instrument operable to determine isotopes in each fluid sample; outputting a signal intensity or signal area; assigning a depth to the signal intensity or the signal area; and determining a corrected isotope ratio by subtracting a signal for the flow-in fluid sample from a signal for the flow-out fluid sample.

Abstract: This disclosure presents a process and system to determine characteristics of a subterranean formation proximate a borehole. Borehole material is typically pumped from the borehole, though borehole material can be used within the borehole as well. Extracted material of interest is collected from the borehole material and prepared for analyzation. Typically, the preparation can be a separation process, a filtering process, a moisture removal process, a pressure control process, a flow control process, a cleaning process, and other preparation processes. The prepared extracted material is placed in a laser dispersion spectroscopy device (LDS) where measurements can be taken. A LDS analyzer can generate results utilizing the measurements, where the results of the extracted material can include one or more of composition parameters, alkene parameters, and signature change parameters. The results can be communicated to other systems and processes to be used as inputs into well site operation plans and decisions.

Abstract: A system includes a discharge tool positioned within a wellbore and configured to generate an electrical discharge that interacts with a rock formation proximate to the discharge tool, wherein the interaction of the electrical discharge with the rock formation vaporizes a portion of the rock formation to generate a discharge plasma. The system further includes an optical emission spectroscopy (OES) sub-system configured to determine an elemental composition of the portion of the rock formation based on optical emission generated by the discharge plasma, wherein at least a portion of the OES sub-system is positioned within the wellbore.

Abstract: This disclosure presents a process to determine characteristics of a subterranean formation proximate a borehole. Borehole material can be typically pumped from the borehole, though borehole material can be used within the borehole as well. Extracted material of interest can be collected from the borehole material and prepared for analyzation. Typically, the preparation can utilize various processes, for example, separation, filtering, moisture removal, pressure control, cleaning, and other preparation processes. The prepared extracted material can be placed in a photoacoustic device where measurements can be taken, such as a photoacoustic imager or a photoacoustic spectroscopy device. A photoacoustic analyzer can generate results utilizing the measurements, where the results of the extracted material can include one or more of fracture parameters, fracture plane parameters, permeability parameters, porosity parameters, and composition parameters.

Abstract: Systems and methods are described for determining the lag time and origin of particles in entrained in a mud stream. A size and shape of the particles may be evaluated at the surface with a visual inspection system, which permits a settling rate to be determined for each of the particles in a non-Newtonian mud stream. Together with an analysis of the pumping schedule, mud properties, trajectory of the wellbore and other fluid dynamics associated with a wellbore operation, an origin of the each of the particles from within the wellbore may be determined. At least one operational parameter for the wellbore operation may be adjusted based on the determined origin of the particles. For example, a clean-out procedure may be initiated if it is determined that particles are settling in an undesirable location in the wellbore.

Abstract: Systems and methods of the present disclosure generally relate to correcting isotope ratio calculations during wellbore operation. A method for correcting isotope ratios during a wellbore operation, comprising: receiving a flow-in fluid sample from a wellbore; receiving a flow-out fluid sample from the wellbore; passing each sample to an analytical instrument operable to determine isotopes in each fluid sample; outputting a signal intensity or signa area: assigning a depth to the signal intensity or the signal area; and determining a corrected isotope ratio by subtracting a signal for the flow-in fluid sample from a signal for the flow-out fluid sample.

Abstract: Various apparatus or methods are arranged to determine a first isotope ratio of an effluent drilling fluid, wherein the effluent drilling fluid is a drilling fluid after the drilling fluid has interacted with a plasma discharge produced via one or more electrodes of a drill bit of a pulsed power drill string disposed in a borehole. A second isotope ratio is estimated based on the first isotope ratio and a downhole reaction generated by the plasma discharge.

Abstract: Systems and methods of the present disclosure generally relate to reporting carbon and hydrogen isotopic ratios during a wellbore operation. A method for detecting isotopic ratios during the wellbore operation, comprises receiving a fluid sample from a wellbore during the wellbore operation; passing the fluid sample to an analytical instrument operable to determine isotopic ratios in the fluid sample; outputting data comprising isotopic ratios for at least carbon and hydrogen; assigning a depth to the data; and transmitting the data based on isotopic ratios encountered during the wellbore operation.

Abstract: Systems and methods are disclosed for using downhole plasma discharge effects to determine porosity and/or permeability of formation material. In some embodiments, a method includes determining a concentration of at least one chemical reaction product in a drilling fluid that has interacted with a plasma discharge proximate formation material. A relation between arc and spark of the plasma discharge is determined based, at least in part, on the at least one chemical reaction product, and at least one of porosity and permeability of the formation material is determined based, at least in part, on the relation between arc and spark.

Abstract: Systems and methods are provided for analyzing isotopes of a gas from a wellbore to determine geological information associated with the wellbore. A drill device can be used to drill rocks or particles in a wellbore, which can cause a gas to be released within the wellbore. Fluid can be pumped into the wellbore as the drill bit drills the rocks or particles and the fluid, along with the gas released, can flow through the wellbore and to a surface of the wellbore. A gas detector can be positioned near the wellbore for detecting an amount of gas and a type of gas in the fluid and gas mixture and transmitting data about the amount and type of the gas to a computing device. The computing device can output data based on the amount and type of gas in the mixture for determining geological information about the wellbore.

Abstract: The present disclosure generally relates to a standalone gas extraction and detection system comprising a gas extraction chamber operable to receive a wellbore fluid and a carrier gas; a gas detection chamber in fluid communication with the gas extraction chamber, the gas detection chamber comprising reflective surfaces operable to receive infrared radiation (IR) and an extracted gas sample from the gas extraction chamber; an open-path detector operable to detect the IR in the gas detection chamber; and a shaft extending through the gas extraction chamber and the gas detection chamber of the standalone gas extraction and detection system.

Abstract: Analysis of chemical and physical properties of drilling and formation fluids associated with pulse power drilling operations that are performed in a borehole extending below a surface into one or more layers of formation material are conducted to determine one or more properties associated with the formation material and/or the drilling and formation fluids.

Abstract: The disclosure provides for systems and methods for removing particle settlement in a heater system. The method includes introducing a fluid into a first heater of the heater system, wherein the first heater is operable to increase the temperature of the introduced fluid. The method further includes actuating a first air agitation unit to discharge a volume of compressed air into the first heater, wherein the compressed air is configured to provide mixing and suspension to particles settled within the first heater through the velocity and expansion of the compressed air to atmospheric pressure. The method further includes discharging a mixture from the first heater comprising the fluid and the particles from the first heater and directing the discharged mixture to a return point in a flow path.

Abstract: A drilling system for drilling a borehole. The drilling system includes a drilling fluid pump operable to circulate fluid through the borehole and a fluid analysis system to analyze returned fluid from the borehole. The fluid analysis system includes a sensor system, a recirculation system, and a control system in electronic communication with the drilling fluid pump and the recirculation system. The sensor system is operable to measure one or more properties of the returned fluid. The recirculation system includes a pump and controllable valves and is operable to control flow of the returned fluid through the fluid analysis system.