Abstract: A focused sampling method comprising: allocating fluid flow from a guard zone through a guard line and from a sample zone through a sample line, the guard zone being positioned at least partially concentrically about the sample zone and the guard zone, and the sample zone being in fluid communication with a formation; pumping, via a common line, a combined fluid flow from the formation through to a discard line for a pre-sampling time period, the combined flow comprising the fluid flow allocated from the guard zone into the guard line and the fluid flow allocated from the sample zone into the sample line; subsequent the pre-sampling time period, discontinuing flow from the guard line into the common line, such that the combined flow comprises only the fluid flow from the sample line; and introducing the combined flow comprising the fluid flow from the sample line into a sample chamber.

Abstract: An apparatus includes a subsurface sensor in a borehole to provide a measurement series, a first processor, and a machine-readable medium having program code. The program code causes the apparatus to obtain the measurement series and generate a combination of functions based on the measurement series, wherein the combination of functions includes a subset of functions from a basis function library. The system also generate a set of values and communicates the set of values to a second processor, wherein the set of values includes a function identifier and corresponding function weight. The second processor is to generate a set of reconstructed measurement series based on the set of values and determine at least one of a formation property, a fluid property, and a well status based on the set of reconstructed measurement series.

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 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 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: 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: A siphon pump chimney can be used in a mini-drillstem test to increase formation fluid flow rates. A formation tester can be coupled to a siphon pump chimney via a wet connect assembly to transfer formation fluid from a fluid-bearing formation. The siphon pump chimney can receive the formation fluid through the wet connect and disperse the formation fluid into a drill pipe that is flowing drilling fluid. The siphon pump chimney can include check valves to prevent the drilling fluid from entering the siphon pump chimney. The siphon pump chimney can be configured to have a variable height that can reduce pressure within the siphon pump chimney to a pressure value that can be close to or less than the formation pressure, which can allow a pump to operate at high flow rates or be bypassed in a free flow configuration.

Abstract: A method and system for performing a pressure test. The method may comprise inserting a formation testing tool into a wellbore to a first location within the wellbore, identifying one or more tool parameters of the formation testing tool, performing a first pre-test with the pressure transducer when the pressure has stabilized to identify formation parameters, inputting the formation parameters and the one or more tool parameters into a forward model, changing the one or more tool parameters to a second set of tool parameters; performing a second pre-test with the second set of tool parameters; and comparing the first pre-test to the second pre-test. A system may comprise at least one probe, a pump disposed within the formation testing tool, at least one stabilizer, a pressure transducer disposed at least partially in the at least one fluid passageway, and an information handling system.

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: A bottom hole assembly (BHA) comprising: a first component of a wet latch assembly, the first component configured for coupling, when extended into the interior flow bore of the BHA, with a second component of the wet latch assembly to provide an assembled wet latch assembly, such that an electrical connection can be made between the first component and the second component; and a formation tester operable for performing a formation test, the formation tester electrically connected with the first component of the wet latch assembly, such that power and/or telemetry can be provided to the formation tester via the assembled wet latch assembly during the formation test.

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 bottom hole assembly (BHA) comprising: a first component of a wet latch assembly, the first component configured for coupling, when extended into the interior flow bore of the BHA, with a second component of the wet latch assembly to provide an assembled wet latch assembly, such that an electrical connection can be made between the first component and the second component; and a formation tester operable for performing a formation test, the formation tester electrically connected with the first component of the wet latch assembly, such that power and/or telemetry can be provided to the formation tester via the assembled wet latch assembly during the formation test.

Abstract: A method comprising: 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: 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: A method and system for performing a pressure test. The method may comprise inserting a formation testing tool into a wellbore to a first location within the wellbore, identifying one or more tool parameters of the formation testing tool, performing a first pre-test with the pressure transducer when the pressure has stabilized to identify formation parameters, inputting the formation parameters and the one or more tool parameters into a forward model, changing the one or more tool parameters to a second set of tool parameters; performing a second pre-test with the second set of tool parameters; and comparing the first pre-test to the second pre-test. A system may comprise at least one probe, a pump disposed within the formation testing tool, at least one stabilizer, a pressure transducer disposed at least partially in the at least one fluid passageway, and an information handling system.

Abstract: A focused sampling method comprising: allocating fluid flow from a guard zone through a guard line and from a sample zone through a sample line, the guard zone being positioned at least partially concentrically about the sample zone and the guard zone, and the sample zone being in fluid communication with a formation; pumping, via a common line, a combined fluid flow from the formation through to a discard line for a pre-sampling time period, the combined flow comprising the fluid flow allocated from the guard zone into the guard line and the fluid flow allocated from the sample zone into the sample line; subsequent the pre-sampling time period, discontinuing flow from the guard line into the common line, such that the combined flow comprises only the fluid flow from the sample line; and introducing the combined flow comprising the fluid flow from the sample line into a sample chamber.

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: Disclosed are methods, systems, and devices for measuring and otherwise processing core samples. In some embodiments, a method includes containing a core sample in a containment vessel including dynamically adjusting pressure within the containment vessel to maintain a phase of fluid within the core sample. Pressure is reduced within the containment vessel. During pressure or following reduction, one or more properties of the fluid in the core sample are measured.

Abstract: An apparatus includes a subsurface sensor in a borehole to provide a measurement series, a first processor, and a machine-readable medium having program code. The program code causes the apparatus to obtain the measurement series and generate a combination of functions based on the measurement series, wherein the combination of functions includes a subset of functions from a basis function library. The system also generate a set of values and communicates the set of values to a second processor, wherein the set of values includes a function identifier and corresponding function weight. The second processor is to generate a set of reconstructed measurement series based on the set of values and determine at least one of a formation property, a fluid property, and a well status based on the set of reconstructed measurement series.

Abstract: Systems and methods for placing well bores and/or portions of completed well systems in a subterranean formation relative to tar mats or other phenomena in the formation are provided. In some embodiments, the methods comprise: identifying a reservoir characteristic associated with a chemical or physicochemical property of a fluid in or proximate to the reservoir characteristic; measuring the property of a fluid in at least a portion of a subterranean formation in two or more locations in the subterranean formation; identifying a variation of the property of the fluid at one or more of the locations in the subterranean formation; and determining a target location or direction for a portion of a well system based at least in part on the variation of the property of the fluid, the well system comprising a borehole penetrating the subterranean formation.