Abstract: Formation testing apparatus including a downhole testing tool for subterranean formation testing within a borehole of a well, the tool including a downhole sampling device having: a test tool body having an outer surface; and assembly extendable out of and retractable into an opening in the outer surface. The assembly includes a seal pad at a first end of the formation probe sampling assembly, the seal pad operable to contact a formation wall of the borehole when the seal pad is extended past the outer surface to thereby define a seal space between the borehole and the seal pad. The seal pad includes at the first end includes a metal plate with a trough therein, the trough defining a closed track in the metal plate, the trough having dimensions to hold a portion of an inflatable elastomeric ring shaped to fit in the trough. Methods of assembly and testing are disclosed.

Abstract: Wellbore equipment used in oil and gas operations can be negatively affected by corrosive fluids. Coatings can be applied to the equipment to help protect the equipment. A field test can be used at a wellsite to ensure the coating is effective. Due to the HSE risks of the corrosive fluids, a proxy fluid can be used instead. The proxy fluid can have similar chemical or physical properties and simulate the corrosive fluid that is anticipated to be present in the wellbore. The wellbore equipment that is coated can be sealed to create a containment area where an initial concentration of the proxy fluid is introduced into the containment area for a period of time. A final concentration of the proxy fluid can be measured after the period of time has elapsed. By calculating the percent change of the proxy fluid, the effectiveness of the coating can be determined.

Abstract: In general, in one aspect, embodiments relate to a method that includes assembling a downhole tool from a plurality of subassemblies with a robotic tool assembly disposed on a subsea tree at a sea-floor in a subsea environment. The method may also include introducing the downhole tool into a wellbore, traversing the wellbore with the downhole tool to reach one or more target depths, performing at least a wellbore operation with the downhole tool at the one or more target depths, and retrieving the downhole tool from the wellbore after performing the wellbore operation.

Abstract: A device for monitoring deposition of a coating comprising a dielectric material during deposition of the coating. The device includes a parallel-plate capacitor having a first plate, and a second plate; a first lead electrically connected to the first plate; a second lead electrically connected to the second plate; and a power supply. The first plate and the second plate are parallel and separated by a spacing with a known spacing thickness. The first lead and the second lead can be electrically connected to positive and negative terminals of the power supply. The device is configured to register a capacitance when the first lead and the second lead are respectively connected to the positive and the negative terminals of the power supply and a dielectric material fills the spacing, and is configured to register no capacitance until the dielectric material fills the spacing.

Abstract: The disclosure presents processes to determine a first formation fluid-second formation fluid boundary from one side of the boundary utilizing a formation tester tool. For example, the formation tester can be utilized in a borehole to determine an engagement point with a subterranean formation and determine one or more, or a combination of, injectable fluids to inject into the subterranean formation. Sensors coupled to the formation tester can measure the rebound pressure of the injected fluids. In some aspects, the fluid density of the collected fluid can be measured. The measured pressure changes and other collected data, can be utilized to determine a first formation fluid-second formation fluid boundary parameter. Other characteristic parameters can also be determined such as wettability parameters, porosity parameters, and capillary effects parameters. The formation tester can collect a core sample and an analyzation of the core sample can be utilized to determine the characteristic parameters.

Abstract: A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.

Abstract: A downhole fluid sampling tool may include: a tool body; a flow port disposed on the tool body; a sample chamber disposed within the tool body and fluidly coupled to the flow port; a pump disposed within the tool body, wherein the pump is configured to pump a fluid through the flow port into the sample chamber; a filter disposed on an inlet of the flow port, wherein the filter is configured to filter the fluid entering the flow port; and a removable filter cover configured to prevent fluid contact with the filter.

Abstract: A downhole tool comprises at least one inlet and a first pump coupled to the at least one inlet via a first flow line. The first pump is to pump at a first pump rate to extract fluid via the at least one inlet from a subsurface formation in which a borehole is created and in which the downhole tool is to be positioned. A sample chamber is coupled to the inlet via a second flow line, and a second pump is coupled to the inlet via the second flow line. The second pump is to pump at a second pump rate to extract the fluid via the at least one inlet from the subsurface formation and for storage in the sample chamber. The first pump rate is greater than the second pump rate.

Abstract: A system includes a pipe string; a wireline cable run through the pipe string; and a downhole tool for formation testing, wherein the downhole tool comprises, an upper assembly, an impeller unit connected to a downhole end of the upper assembly, wherein the impeller unit comprises a first impeller coupled to a second impeller by a shaft, a first flowline having a first end that is open to the formation, a packer unit that isolates a portion of a borehole surrounding the first end of the first flowline from the rest of the borehole, and a tool string connected to the first flowline, wherein the tool string hydraulically connects the packing device to the upper assembly.

Abstract: A microsampling device for taking fluid samples in a wellbore. The microsampling device may comprise a microsampling tube in which one or more microsamplers disposed in the microsampling tube. Additionally, the microsampling device may comprise a fluid flow line connected to the microsampling tube in which a fluid sample traverses and a secondary fluid flow line in which at least a part of the fluid sample may traverse from the microsampling tube through the secondary fluid flow line and into a wellbore.

Abstract: A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.

Abstract: The disclosure presents processes to determine a first formation fluid-second formation fluid boundary from one side of the boundary utilizing a formation tester tool. For example, the formation tester can be utilized in a borehole to determine an engagement point with a subterranean formation and determine one or more, or a combination of, injectable fluids to inject into the subterranean formation. Sensors coupled to the formation tester can measure the rebound pressure of the injected fluids. In some aspects, the fluid density of the collected fluid can be measured. The measured pressure changes and other collected data, can be utilized to determine a first formation fluid-second formation fluid boundary parameter. Other characteristic parameters can also be determined such as wettability parameters, porosity parameters, and capillary effects parameters. The formation tester can collect a core sample and an analyzation of the core sample can be utilized to determine the characteristic parameters.

Abstract: A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.

Abstract: A downhole PVT tool for performing in-situ formation fluid phase behavior characterizations in a wellbore using pressure, volume, and temperature (PVT) measurements of the formation fluid while continuing to pump the formation fluids. The disclosed downhole PVT tool includes an intake mandrel and utilizes two individual pumps to split the formation fluid to perform PVT measurements during the fluid pump out. The downhole PVT tool, two-pump configuration permits a first pump to be used to pump formation fluid along a first flowpath and a second pump to be used to pump formation fluid along a second flowpath, with one or more sensors deployed along one of the flowpaths to perform fluid and/or gas phase behavior measurements to determine one or more properties of the formation fluid in-situ. The first pump may be utilized in the phase behavior analysis while the second pump simultaneously continues flow-through pumping of the formation fluid.

Abstract: A method for performing an acid stimulation operation using a downhole tool includes conveying the downhole tool in a borehole that is formed in a subsurface formation. The downhole tool includes a chamber to store stimulation fluid comprising a stimulation acid. The downhole tool includes a fluid injector that is fluidly coupled to an output of the chamber via a flow line of the downhole tool. The method includes coating the flow line with an acid resistant fluid. The method includes injecting, from the fluid injector via the flow line, the stimulation fluid into the subsurface formation that is released through the output of the chamber.

Abstract: An apparatus comprises a subsurface sensor to be positioned in a wellbore formed in a subsurface formation, wherein the subsurface sensor is to detect subsurface measurements. The apparatus includes a processor and a machine-readable medium having program code executable by the processor to cause the processor to generate a combination of functions based on the subsurface measurements, wherein the combination of functions is a subset of functions from a library of functions. The program code is executable by the processor to cause the processor to determine at least one function parameter of at least one function of the combination of functions and determine at least one formation property of the subsurface formation based on the at least one function parameter.

Abstract: A method and system for measuring drilling fluid filtrate. The method may comprise disposing a downhole fluid sampling tool into a wellbore at a first location, activating a pump to draw a solids-containing fluid disposed in the wellbore into the downhole fluid sampling tool, drawing the drilling fluid with the pump across the at least one filter to form a drilling fluid filtrate, drawing the drilling fluid filtrate with the pump through the channel to the at least one sensor section, and measuring the drilling fluid filtrate with the at least one sensor. A system may comprise a downhole fluid sampling tool. The downhole fluid sampling tool may comprise at least one multi-chamber section, at least one sensor section, at least one filter, a pump, and a channel.

Abstract: A downhole probe can be utilized in a wellbore to accurately determine a relative depth between measurement locations. The downhole probe includes a measurement unit for taking downhole measurements and a detachable anchor that can grip a wellbore wall to maintain a fixed location. The measurement unit may be moved relative to anchor between the measurement locations to unspool a tether coupled between the anchor and the measurement unit. The length of the tether unspooled may provide a more accurate indication of the relative distance between the measurement locations than surface-based measurements. The detachable anchor may be retrieved for deployment at additional measurement locations or may be abandoned in the wellbore.

Abstract: A method including, without removing a BHA from a wellbore of a well extending into a formation, extending, into an interior flow bore of the BHA, a first component of a wet latch assembly to provide an extended first component of the wet latch assembly, conveying downhole via a wireline cable, from a surface through an interior flow bore provided by a drill string, a second component of the wet latch assembly, and coupling the second component of the wet latch assembly with the extended first component of the wet latch assembly such that an electrical connection is established between the first component and the second component and between the BHA and the surface via the wireline cable, and testing the formation with a formation tester of the BHA, while providing power and/or data telemetry for the formation tester via the wet latch assembly and the wireline cable.

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.