Abstract: An example method comprises collecting formation temperature data along a wellbore extending into a subterranean formation, determining test operating parameter values, performing a wellbore hydraulic simulation of the response of wellbore fluid conditions to the test operating parameter values and the formation temperature data, determining whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem, and initiating a test based on the determination whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem.

Abstract: Various methods for detecting and accounting for the effects of half-stroking by a pump are provided. In one embodiment, a method includes operating a pump of a downhole tool to pump fluid from a formation through the downhole tool and determining pressure differentials between a formation pressure and pressure of the fluid within the downhole tool. The pressure differentials for each of a forward stroke and reverse stroke of the pump can be summed and then compared to enable identification of onset of half-stroking by the pump. Additional systems, devices, and methods are also disclosed.

Abstract: Obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus, and then obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus. A wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is then determined based on the first and second optical spectral data, and a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is determined based on the first and second optical spectral data.

Abstract: A system includes a downhole formation fluid sampling tool and a processor. An optical spectrometer of the downhole formation fluid sampling tool is able to measure an optical characteristic of a formation fluid flowing through the downhole formation fluid sampling tool over a plurality of wavelengths. The optical spectrometer generates optical spectra data indicative of this optical characteristic. The processor is designed to receive the optical spectra data generated by the optical spectrometer and to estimate a formation volume factor of the formation fluid based on the optical spectra data.

Abstract: A packer assembly with an enhanced sealing layer is provided. The packer assembly may have an outer bladder with drains. The packer assembly may further have an inflatable inner packer disposed inside the outer bladder such that inflation of the inner packer causes the outer bladder to expand. End pieces may be coupled to the inner bladder and the outer bladder, and flowlines may be in fluid communication with the drains and the end pieces. A piston ring may reinforce the packer assembly. The piston ring may have three or more passive pistons which expand with the packer assembly during testing.

Abstract: Obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus, and then obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus. A wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is then determined based on the first and second optical spectral data, and a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is determined based on the first and second optical spectral data.

Abstract: A system and method collects one or more measurements within a borehole formed in a subsurface reservoir. The system and method provides a first downhole component having an expandable element and a first port formed in a layer of the expandable element. A wireless transceiver is connected to the first downhole component, wherein the wireless transceiver is adapted to transmit one or more wireless signals within the borehole. A first wireless sensor located at the first port and remotely with respect to the wireless transceiver, wherein the first wireless sensor is configure to receive the one or more wireless signals and collect at least one measurement within the borehole or perform at least one task related to the borehole or subsurface reservoir about the borehole.

Abstract: A system includes a downhole formation fluid sampling tool and a processor. An optical spectrometer of the downhole formation fluid sampling tool is able to measure an optical characteristic of a formation fluid flowing through the downhole formation fluid sampling tool over a plurality of wavelengths. The optical spectrometer generates optical spectra data indicative of this optical characteristic. The processor is designed to receive the optical spectra data generated by the optical spectrometer and to estimate a formation volume factor of the formation fluid based on the optical spectra data.

Abstract: According to certain embodiments, formation fluid properties, such as gas-oil ratio (GOR), formation volume factor (FVF), and density, may be measured at multiple times during sampling. In one embodiment, data representing the measured properties is analyzed and a characteristic of interest is determined through extrapolation from the analyzed data. Various other methods and systems are also disclosed.

Abstract: A method for identifying the type of a sampled formation fluid, such as a hydrocarbon, is provided. In one embodiment, the method includes measuring absorbance by a sample of a formation fluid at multiple wavelengths of electromagnetic radiation with a spectrometer. The method also includes distinguishing between multiple fluid types to identify a fluid type of the sample most likely to match an actual fluid type of the sample based on the measured absorbance at two or more wavelengths of the multiple wavelengths. Additional systems, devices, and methods are also disclosed.

Abstract: A tool to be used within a wellbore including a wall, the wellbore extending through a formation including formation fluid, includes a first packer and a second packer. The first packer includes a packer port to enable formation fluid flow through the first packer, with the second packer spaced from the first packer. The first packer and the second packer are expandable to abut the wellbore wall to form an interval within the wellbore between the first packer and the second packer, in which the tool further includes an interval port in fluid communication with the interval.

Abstract: A method for measuring asphaltene content of a crude oil is provided. In one embodiment, the method includes measuring an optical density of a live crude oil within a well and calculating a formation volume factor of the live crude oil based on the measured optical density. The method also includes determining asphaltene content of the live crude oil based on the measured optical density and the calculated formation volume factor of the live crude oil. Additional methods, systems, and devices are also disclosed.

Abstract: A method and apparatus for performing water based mud-filtrate contamination monitoring in real time through evaluation of downhole water sampling.

Abstract: A sample that includes formation content from a subsurface formation and other sample constituents is obtained while the sample is in close proximity to the subsurface formation. While downhole, the formation content is separated from the other sample constituents by passing the sample through an oil-wet porous plate, a water-wet porous plate, or through both plates, and analyzed. Various petrophysical properties of the formation content may be determined. To further separate the formation content, one may pass the sample through a mesh, pass the sample into an expansion chamber, or draw the sample into a chamber using a moveable piston. The formation content may be analyzed downhole using, for example, a mass spectrometer, FTIR, or chromatograph. The hydrocarbon contribution from oil based drilling fluid can be accounted for. Alternatively, a capsule may be charged with “live” formation content and conveyed uphole to be analyzed.

Abstract: An apparatus comprising a downhole tool configured for conveyance within a borehole penetrating a subterranean formation, wherein the downhole tool comprises: a probe assembly configured to seal a region of a wall of the borehole; a perforator configured to penetrate a portion of the sealed region of the borehole wall by projecting through the probe assembly; a fluid chamber comprising a fluid; and a pump configured to inject the fluid from the fluid chamber into the formation through the perforator.

Abstract: A method includes pumping fluid from outside of a downhole tool through a flowline of the downhole tool with a pump and taking first measurements, using at least one sensor, within the flowline during a first stage of pumping the fluid. The method further includes estimating a saturation pressure of the fluid, via a processor, based on the first measurements and a saturation pressure model generated based on second measurements taken using the at least one sensor during a second stage of pumping the fluid, and operating the pump to maintain a fluid pressure in the flowline greater than the estimated saturation pressure.

Abstract: A system includes a downhole formation fluid sampling tool and a processor. An optical spectrometer of the downhole formation fluid sampling tool is able to measure an optical characteristic of a formation fluid flowing through the downhole formation fluid sampling tool over a plurality of wavelengths. The optical spectrometer generates optical spectra data indicative of this optical characteristic. The processor is designed to receive the optical spectra data generated by the optical spectrometer and to estimate a formation volume factor of the formation fluid based on the optical spectra data.

Abstract: A system includes a downhole formation fluid sampling tool. The system also includes an optical spectrometer of the downhole formation fluid sampling tool and a processor. The optical spectrometer is able to measure an optical characteristic of a formation fluid flowing through the downhole formation fluid sampling tool over a plurality of wavelengths. The optical spectrometer is designed to generate optical spectra data indicative of the optical characteristic. The processor is able to receive the optical spectra data generated by the optical spectrometer, to predict a parameter corresponding to one component of multiple components of the formation fluid based on the optical spectra data, and to calculate an uncertainty in the predicted parameter based on the optical spectra data.

Abstract: An optical spectrometer includes a near black body light source, a reference detector in a first optical path and a single measurement detector in a second optical path. A sample cell including a fluid flow line may be positioned in the second optical path upstream of the measurement detector. Optical energy ma be emitted at a plurality of filament temperatures and first and second sets of optical intensities measured at the reference and measurement detectors. The first and second sets of optical intensities may be processed to compute a substantially continuous transmittance spectrum of a fluid sample in the fluid flow line by inverting the acquired optical intensity measurements.

Abstract: A method for determining formation fluid sample quality includes analyzing sample capture data to identify distinguishing features indicative of whether a successful sample capture has occurred within a downhole tool. The method further includes prioritizing, based on the analysis, the sample capture data for transmission to a surface system.