Abstract: A method may comprise positioning a downhole fluid sampling tool into a wellbore; performing a pressure test operation within the wellbore; performing a pumpout operation within the wellbore; identifying one or more formation parameters at least in part from the at least one pressure test operation or the at least one pumpout operation; building a correlation model that relates a pumpout trend to the one or more formation parameters; determining a time when the downhole fluid sampling tool takes a clean fluid sample utilizing at least the correlation model; and acquiring the clean fluid sample with the downhole fluid sampling tool from the wellbore. Additionally, a system may comprise a downhole fluid sampling tool configured to: perform a pressure test operation within a wellbore; and perform a pumpout operation within the wellbore; and.

Abstract: A formation sampling tool including a plurality of ferrofluidic seals for sealing the formation sampling tool against a wellbore wall of a wellbore, each adjacent pair of the plurality of ferrofluidic seals defining a formation fluid inflow section through which formation fluid enters the formation sampling tool via fluid inflow lines, wherein a first ferrofluidic seal of the plurality of ferrofluidic seals is distal a drill bit, and wherein a last ferrofluidic seal of the plurality of ferrofluidic seals is proximate the drill bit; a formation fluid sampling line, wherein the formation fluid sampling line is in fluid communication with the one or more fluid inflow lines; one or more sensors in fluid communication with the one or more fluid inflow lines and/or the formation fluid sampling line; and a pump configured to pump formation fluid into the formation sampling tool via each of the formation fluid inflow sections.

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 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 coring tool includes a coring bit to cut and detach a core sample from a subsurface formation formed in a borehole. The coring tool includes a pressure vessel that includes a core chamber to store the core sample at a pressure and a piston positioned adjacent to the core chamber. The pressure vessel includes a chamber adjacent to the piston and a gas reservoir to store a gas that expands as the gas is moved to a surface of the borehole. The pressure vessel includes a valve coupled to an inlet of the chamber and an outlet of the gas reservoir, wherein the gas is to flow into the chamber when the valve is open to move the piston to cause an increase in the pressure of the core chamber.

Abstract: A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property.

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 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 method may comprise positioning a downhole fluid sampling tool into a wellbore, performing a pressure test operation within the wellbore, performing a pumpout operation within the wellbore, identifying when a clean fluid sample may be taken by the downhole fluid sampling tool from at least the pressure test operation and the pumpout operation, and acquiring the clean fluid sample from the wellbore. A system may comprise a downhole fluid sampling tool and an information handling machine. The downhole fluid sampling tool may further comprise one or more probes attached to the downhole fluid sampling tool, one or more stabilizers attached to the downhole fluid sampling tool, and a sensor placed in the downhole fluid sampling tool configured to measure drilling fluid filtrate.

Abstract: An apparatus includes a formation tester tool to be positioned in a borehole within a formation, wherein the formation tester tool comprises a pressure sensor and a pad that is radially extendable with respect to an axis of the formation tester tool, and wherein the pressure sensor is inside the pad. The formation tester tool includes first and second inner radially extendable packers that are axially above and below the pad, respectively, with respect to the axis of the formation tester tool. The apparatus includes a first outer radially extendable packer that is axially above the first inner radially extendable packer with respect to the axis of the formation tester tool and a second outer radially extendable packer that is axially below the second inner radially extendable packer with respect to the axis of the formation tester tool.

Abstract: A method includes positioning a formation tester tool into a borehole formed within a formation and radially expanding a first and second radially extendable packers of the formation tester tool out from the formation tester tool to the formation to form a sealed volume between the first radially extendable packer and the second radially extendable packer. The method includes radially extending a pad of the formation tester tool that is positioned between the first radially extendable packer and the second radially extendable packer to form a sealed connection volume between the formation and a pressure sensor within the pad. The method includes acquiring a first pressure measurement, using the pressure sensor, from fluids in the sealed connection volume and extracting fluid from the sealed volume to reduce pressure around the pad. The method includes acquiring a second pressure measurement, using the pressure sensor, from fluids in the sealed connection volume.

Abstract: A device for coating an interior surface of a housing defining a volume comprising a plurality of reactant gas sources including reactant gases for one or more surface coating processes; first and second closures to sealingly engage with an inlet and outlet of the volume of the housing to provide an enclosed volume; a delivery line fluidically coupled to the first closure and the plurality of reactant gas sources to deliver the reactant gases to the enclosed volume; and an output line fluidically coupled to the second closure to remove one or more reactant gases, byproduct gases, or both from the enclosed volume. A method for coating an interior surface of a housing is also provided.

Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Abstract: A downhole tool for performing an acid stimulation operation includes a chamber and at least one acid resistant container to store a stimulation fluid comprising a stimulation acid. The at least one acid resistant container can be placed in the chamber prior to conveying the downhole tool in a borehole. The downhole tool can include a fluid injector fluidly coupled to an output of the chamber. After the downhole tool is positioned at a location in the borehole where the stimulation fluid is to be injected into a subsurface formation surrounding the borehole, the at least one acid-container can be opened such that the stimulation fluid can flow from the output of the chamber to the fluid injector. The fluid injector can inject the stimulation fluid into the subsurface formation.

Abstract: A method comprises flowing a mud into a wellbore, wherein the mud has a mud composition and has a weight in a defined range. The method includes introducing a fluid pill into the mud flowing into the wellbore, wherein the fluid pill has an injection fluid with an injection composition that is different from the mud composition. A particulate has been added to the injection fluid to increase the weight of the fluid pill to be in the defined range. After flowing the mud into the wellbore such that the fluid pill is positioned in a zone of the wellbore: filtering out the particulate from the injection fluid; injecting, after the filtering, the injection fluid into the zone; measuring a downhole parameter that changes in response to injecting the injection fluid into the zone; and determining a property of the formation of the zone based on the measured downhole parameter.

Abstract: A device for coating an interior surface of a housing defining a volume comprising a plurality of reactant gas sources including reactant gases for one or more surface coating processes; first and second closures to sealingly engage with an inlet and outlet of the volume of the housing to provide an enclosed volume; a delivery line fluidically coupled to the first closure and the plurality of reactant gas sources to deliver the reactant gases to the enclosed volume; and an output line fluidically coupled to the second closure to remove one or more reactant gases, byproduct gases, or both from the enclosed volume. A method for coating an interior surface of a housing is also provided.

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: To reduce effects of artificial alteration of measured formation pressure downhole, an iterative procedure for accurately measuring formation pressure in drawdown/buildup operations is presently disclosed. During buildup/drawdown operations, pressure measurements are taken by pressure sensors in concentric volumes sealed to the formation. After each buildup operation, pressure in the outer concentric volume is lowered using a pressure sensor therein to a progressively lower pressure until a pattern for the pressure trend stabilizes asymptotically. The true formation pressure is taken after a final buildup operation once pressure measurements stabilize.

Abstract: Disclosed herein are methods and systems for capture and measurement of a target component. A fluid sampling tool for sampling fluid from a subterranean formation may include a sample chamber having a fluid inlet, wherein the sample chamber is lined with a coating of a material that can reversibly hold a target component.

Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.