Abstract: Described herein are systems, apparatuses, processes (also referred to as methods), and computer-readable media (collectively referred to as “systems and techniques”) for improving an accuracy of determinations made using data sensed in a wellbore. Such systems and techniques may use a combination of sampled data and simulated data to generate updated datasets that may be used to make evaluations about how well a casing is cemented to subterranean formations where a wellbore is located.

Abstract: A method includes flowing gas within a chamber for first process parameters at a predetermined point in a laser focal plane and simulating the step of flowing gas within the chamber based on the value of the flow characteristic of the gas at the predetermined point in the laser focal plane so that a value of a simulated-flow characteristic of the gas at a predetermined point away from the laser focal plane is identified. The method comprises comparing the value of the simulated-flow characteristic of gas at the predetermined point away from the laser focal plane to a desired value of the simulated-flow characteristic and flowing gas within the chamber for second differing process parameters, when the value of the simulated-flow characteristic of the gas at the predetermined point away from the laser focal plane differs from the desired value of the simulated-flow characteristic is outside a predetermined range.

Abstract: A method and system for correlating two or more logs. The method may include reviewing an openhole log to identify one or more depths within a wellbore for testing, disposing a fluid sampling tool into the wellbore, creating a correlation log with the fluid sampling tool, depth-matching the correlation log to the openhole log to create a relative shift table, and moving the fluid sampling tool to the one or more depths within the wellbore based at least in part on the relative shift table. The system may include a fluid sampling tool disposed in a wellbore to create a correlation log and an information handling system connected to the fluid sampling tool.

Abstract: Systems and methods are provided for facilitating continuous affinity-based separation of phases in multi-phase formation fluid in a downhole environment. A system can comprise a formation sampler that samples a formation to gather multi-phase formation fluid in a continuous flow through a wellbore during a testing pump out of the formation. The system can also comprise a phase separator comprising one or more affinity-based separators that continuously separates one or more phases of the multi-phase formation fluid through either or both diffusion or flow while downhole in the wellbore during the testing pump out.

Abstract: Described herein are systems and techniques for improving an accuracy of determinations made using data sensed in a wellbore or in a laboratory. Nuclear magnetic resonance (NMR) sensing devices may be used to collect data in a wellbore or lab. NMR sensing devices include a magnet (e.g., a permanent magnet or electromagnet) that provides a magnetic field that aligns the spins of protons in substances near the NMR sensing device. The magnetic field strength provided by the magnet of the NMR sensing device affects the sensitivity of the NMR sensing device and affects frequencies that the NMR sensing device effectively uses when the NMR sensing device operates. Systems and techniques of the present disclosure may measure concentrations of lithium in brine deposits when identifying particular brine deposits that include sufficient lithium concentrations to justify extracting lithium from those particular brine deposits.

Abstract: This present disclosure seals the light propagation path in an optical interconnection element from external contaminants. The optical interconnection element includes a reflective surface, which can also be sealed from external contaminants Additional novel concepts include all enclosed sealed regions of the optical interconnection element being fluidly connected and making the final seal of the optical interconnection element with a thin plate, which can bend reducing the pressure differential between the ambient environment and the sealed internal volume of the optical interconnection element.

Abstract: Systems and methods are provided for using sequential residual symbolic regression for petrophysical modeling. An example method can include receiving training data for modeling one or more petrophysical parameters based on reservoir formation data; performing symbolic regression using the training data to obtain a first set of symbolic regression models; determining a first residual based on the training data and a first symbolic regression model from the first set of symbolic regression models; performing symbolic regression using the first residual to obtain a second set of symbolic regression models; and updating the first symbolic regression model based on a second symbolic regression model from the second set of symbolic regression models to yield a first revised symbolic regression model.

Abstract: Aspects of the subject technology relate to systems and methods for configuring links or switches that connect analog circuit elements. These analog circuit elements may be connected to a plurality of sensors that may sense different types of data. For example, these sensors may sense acoustic data, electromagnetic (EM) data, temperature, pressure, and possibly other metrics that may be located in a wellbore of an oil or gas well. These analog circuits may be configured as needed (e.g., on-the-fly) to perform optimized types of computations that may include the solving of differential equations. Examples of analog circuits that may be incorporated into a sensing system include yet are not limited to operational amplifier circuits or memcomputing devices, other components, or combinations thereof. Configured analog circuits may be coupled to digital electronics that perform other functions.

Abstract: Herein are described methods and systems for characterizing noise and noise level during downhole pressure testing and/or sampling operations. Methods and systems may identify and quantify the noise level of a formation pressure testing and/or sampling operations by measuring pressures with the probe pressure sensor and the tool pressure sensor with and without extension of the dual probe and closing the bubble point valve that connects the probe fluid passageway to the tool fluid passageway.

Abstract: Aspects of the subject technology relate to systems, methods, and computer readable media for determining a parameter of a formation based on withdrawal of an injected tracer solution. A changing concentration profile of a volume of tracer solution that is withdrawn from a formation is measured. A varying simulated concentration profile associated with the tracer solution in a simulated formation is generated by modifying simulated formation parameters of the simulated formation. The varying simulated concentration profile is compared to the changing concentration profile of the volume of tracer solution that is withdrawn from the formation. A parameter of the formation is identified based on a comparison of the varying simulated concentration profile to the changing concentration profile of the volume of tracer solution withdrawn from the formation.

Abstract: Aspects of the subject technology relate to systems, methods, and computer readable media for determining permeability anisotropy of a formation. A formation tester can be set at a location within a wellbore. A plurality of probes can be set into a formation at the location. A tracer solution can be injected into the formation. A fluid can be continuously withdrawn from the formation over a time interval through at least one of the plurality of probes. The fluid can comprise a volume of the tracer solution into the formation. A changing concentration of the tracer solution that is withdrawn from the formation over the time interval can be measured based on the volume of the tracer solution that is withdrawn from the formation over the time interval. A permeability anisotropy of the formation can be determined based on the changing concentration of the tracer solution.

Abstract: This disclosure presents systems and processes to collect elemental composition of target fluid and solid material located downhole of a borehole. Waveguides can be utilized that include capillary optics to deliver emitted high energy into a container or a conduit and then to detect the high energy. A source waveguide can be used to emit the high energy into the target fluid and a detector waveguide can collect resulting measurements. Each waveguide can include a protective sheath and a pressure cap on the end of the capillary optics that are proximate the target fluid, to protect against abrasion and target fluid pressure. In other aspects, a pulsed neutron tool can be utilized in place of the waveguides to collect measurements. The collected measurements can be utilized to generate chemical signature results that can be utilized to determine the elemental composition of the target fluid or of the solid material.

Abstract: Described herein are systems and techniques for improving an accuracy of determinations made using data sensed in a wellbore or in a laboratory. Nuclear magnetic resonance (NMR) sensing devices may be used to collect data in a wellbore or lab. NMR sensing devices include a magnet (e.g., a permanent magnet or electromagnet) that provides a magnetic field that aligns the spins of protons in substances near the NMR sensing device. The magnetic field strength provided by the magnet of the NMR sensing device affects the sensitivity of the NMR sensing device and affects frequencies that the NMR sensing device effectively uses when the NMR sensing device operates. Systems and techniques of the present disclosure may measure concentrations of lithium in brine deposits when identifying particular brine deposits that include sufficient lithium concentrations to justify extracting lithium from those particular brine deposits.

Abstract: A method and system for disposing a fluid sampling tool into a wellbore, taking a plurality of fluid samples with the fluid sampling tool, identifying a plurality of asphaltene onset pressures (AOP) downhole based at the least on the plurality of fluid samples. The method may further comprise forming an AOP map from at least the plurality of AOPs, identifying a laboratory property from at least one of the plurality of fluid samples; and developing a relational model between at least one of the plurality of AOPs and the laboratory property. The system may include a fluid sampling tool with one or more probes for injecting the one or more probes into a wellbore and taking a plurality of fluid samples from the wellbore.

Abstract: Systems and methods are provided for determining ion concentration of a fluid downhole using a polymer matrix packaged in a cartridge. An example method can include disposing a cartridge within a flow path of a sensor. The cartridge includes a bracket; a retainer formed of a porous material having pores sized to allow a fluid to flow therethrough; and a substrate comprising a polymer matrix embedded with an ion-indicator, the substrate configured to interact with the fluid and to modify an optical characteristic of the substrate according to an ion concentration of the fluid. The method further includes illuminating the substrate; detecting a change in an optical characteristic of the substrate, the change indicative of the ion concentration of the fluid; and determining the ion concentration of the fluid.

Abstract: Described herein are systems, apparatuses, processes (also referred to as methods), and computer-readable media (collectively referred to as “systems and techniques”) for receiving data from or associated with apparatus (e.g., tools) deployed down a wellbore at speeds not previously possible. Information or data sent from a downhole tool for receipt by computers located at the surface of the Earth is often bandwidth limited for various reasons. Systems and techniques of the present disclosure allow for disposable fiber optic cables to be deployed into a wellbore that may be dedicated to sending data or sensed information uphole to a computer. This allows for additional amounts of data or sensed information to be sent to the computer when other communication mechanisms or pathways associated with a wellbore are bandwidth limited.

Abstract: A method for estimating a thickness for each of a plurality of nested tubulars may include disposing an electromagnetic (EM) logging tool in a wellbore, transmitting an electromagnetic field from the transmitter into one or more tubulars to energize the one or more tubulars with the electromagnetic field thereby producing an eddy current, and measuring the electromagnetic field generated by the eddy current. Additionally, the method may include defining a prior distribution of at least one pipe thickness log based on the plurality of measurements, processing a first set of measurement depth points to estimate one or more tubulars at one or more depths in the wellbore, computing a posterior distribution of the thickness log based at least in part on the prior distribution and the one or more thicknesses, and determining a second set of measurement depth points to process based on the posterior distribution.

Abstract: Placing sensors beyond the outer diameter of a casing of a borehole can allow improved sensor data collection of the casing characteristics, such as its bonding to the subterranean formation, of the subterranean formation characteristics such as wettability or porosity, or the reservoir characteristics, such as drainage direction and rate. Sensors can be positioned by drilling a hole through the casing, such as using a drill and inserting the sensor into or through the hole. In some aspects, a sealer, like a resin can be used to fluidly deal the hole. In some aspects, the sensor can be coupled to power or communications located interior of the inner diameter of the casing. In some aspects, the sensor can be wirelessly powered or can wirelessly communicate with other borehole systems. In some aspects, a hole can be made into the subterranean formation to allow sensor placement deeper into the formation.

Abstract: Carbon Capture, Utilization, and Storage (CCUS) is a relatively new technology directed to mitigating climate change by reducing greenhouse gas emissions. Current and new government requirements require proof that carbon dioxide (CO2) is either sequestered in a stable form or safely stored for long periods of time. In instances when the CO2 is sequestered through mineral formation, the need for long-term monitoring can be reduced, as the stability of the sequestered CO2 is inherent based on a chemical change in subterranean rocks. The reactions between CO2 and rock formations are influenced by numerous factors, including temperature, pressure, fluid composition, and the mineralogy of the formation. Furthermore, these reactions occur over large spatial areas and long timescales, making them difficult to monitor directly.