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: 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 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 formation tester consists of an upper assembly, an impeller unit, a straddle packer unit, and an inverted reservoir description tool string. The upper assembly seals off the wireline cable at the rig and connects the wireline cable to the formation tester. The impeller unit includes an upper turbine which converts hydraulic power from circulation of drilling mud into mechanical power. The mechanical power is used to drive a lower impeller which is capable of pumping formation fluids at high flow rates. The straddle packer unit isolates a portion of the formation tester which is open to the borehole to allow entry and exit of formation fluids through the formation tester. The inverted reservoir description tool string contains a combination of formation description modules which are inverted from traditional reservoir description tool modules to allow fluid flow paths to bypass electrical components.

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 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: 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: 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 formation tester consists of an upper assembly, an impeller unit, a straddle packer unit, and an inverted reservoir description tool string. The upper assembly seals off the wireline cable at the rig and connects the wireline cable to the formation tester. The impeller unit includes an upper turbine which converts hydraulic power from circulation of drilling mud into mechanical power. The mechanical power is used to drive a lower impeller which is capable of pumping formation fluids at high flow rates. The straddle packer unit isolates a portion of the formation tester which is open to the borehole to allow entry and exit of formation fluids through the formation tester. The inverted reservoir description tool string contains a combination of formation description modules which are inverted from traditional reservoir description tool modules to allow fluid flow paths to bypass electrical components.

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 contrast device for analysis of a wellbore fluid includes: a substrate; and a contrast agent adhered to the substrate, wherein the contrast agent is configured to respond to an analyte within the wellbore fluid thereby altering a measurable characteristic of the contrast agent. A system including the contrast device may further include an energy source and a detector to facilitate measuring the characteristic of the contrast agent.

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 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 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 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.