Abstract: Fluids are pumped into the wellbore by pulsing the fluids at a variable, positive pressure relative to the geologic formation until a first pressure threshold in the first fracture zone is satisfied. The pumping results in a first pressure profile in the first fracture zone representing pressures in the first fracture zone over time responsive to the pumping, and a second pressure profile in the second zone representing pressures in the second zone over time responsive to the pumping. In response to determining that the first pressure threshold is satisfied, the fluids are ceased to pump into the wellbore for a duration of time. After the duration of time, the fluids are re-pumped into the wellbore by pulsing the fluids at the variable, positive pressure relative to the geologic formation until a second pressure threshold in the first fracture zone in the first fracture zone is satisfied.

Abstract: A sensor for measuring a density of a fluid is provided. The sensor (200) includes a flow tube (104) for receiving the fluid and a vibration driver (102) coupled to the flow tube, the vibration driver configured to drive the flow tube to vibrate. The sensor also includes a vibration detector (106) coupled to the flow tube, the vibration detector detecting characteristics related to the vibrating flow tube, and a distributed temperature sensor (202) coupled to the flow tube, the distributed temperature sensor measuring a temperature of the flow tube as the flow tube vibrates. The sensor further includes measurement circuitry (110) coupled to the vibration detector and the distributed temperature sensor, the measurement circuitry determining a density of the fluid from the detected characteristics related to the vibrating flow tube and the measured temperature of the flow tube.

Abstract: Methods for determining the quality of data gathered in a wellbore in a subterranean formation including (a) collecting a formation fluid sample in the wellbore in the subterranean formation using a formation tester for receiving the formation fluid, wherein the formation tester is lowered to at least one depth in the wellbore in the subterranean formation by a conveyor; (b) acquiring a wellbore measurement (“WM”) from the least one depth with the formation tester; (c) determining from the WM a measured quality value (“MQV”); (d) assigning a threshold value (“TV”) to the MQV; (e) assigning a range value (“RV”) to the MQV, based on geometric scaling of the TV, the RV defining the limits of the MQV above and below the TV; and (f) calculating a score value (“SV”) based on the MQV, the TV, and the RV, wherein the SV is a number between 0 and 2*TV, and wherein the quality of the WM increases as the SV increases.

Abstract: A method of determining a reservoir parameter of a subterranean formation comprising: initiating an initial pressure pulse in the subterranean formation; initiating a series of subsequent pressure pulses in the subterranean formation until the reservoir parameter may be determined, wherein each subsequent pressure pulse is optimized utilizing analytical and/or numerical simulation models; and determining the reservoir parameter.

Abstract: In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sampled is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnet provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (e.g., without opening the sample chamber).

Abstract: In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sampled is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnet provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (e.g., without opening the sample chamber).

Abstract: Apparatus and methods for downhole formation testing including use of a probe having inner and outer channels adapted to collect or inject injecting fluids from or to a formation accessed by a borehole. The probe straddles one or more layers in laminated or fractured formations and uses the inner channels to collect fluid.

Abstract: An instrument for determining fluid properties is provided. The instrument (300) includes a tube (304) receiving the fluid, a single magnet (302) attached to the tube, and a single coil (306) wound around the single magnet. The single coil is coupled to a pulse current source (312) and receives a pulse current that creates a magnetic field in the single coil, the created magnetic field interacting with the single magnet to drive the tube to vibrate. The instrument further includes a detector (306) coupled to the tube, wherein the detector is coupled to measurement circuitry (310) and detects properties of the tube as it vibrates, and the measurement circuitry determines the fluid properties based on the detected properties. The instrument also includes a housing (314) enclosing the tube, the single magnet, and the single coil wound around the single magnet.

Abstract: A system for pressure testing a formation includes a downhole tool configured to measure formation pressure, storage containing pressure parameters of a plurality of simulated formation pressure tests, and a formation pressure test controller coupled to the downhole tool and the storage. For each of a plurality of sequential pressure testing stages of a formation pressure test, the formation pressure test controller 1) retrieves formation pressure measurements from the downhole tool; 2) identifies one of the plurality of simulated formation pressure tests comprising pressure parameters closest to corresponding formation pressure values derived from the formation pressure measurements; and 3) determines a flow rate to apply by the downhole tool in a next stage of the test based on the identified one of the plurality of simulated formation pressure tests.

Abstract: Systems and methods for downhole formation testing based on the use of one or more elongated sealing pads disposed in various orientations capable of sealing off and collecting or injecting fluids from elongated portions along the surface of a borehole. The various orientations and amount of extension of each sealing pad can increase the flow area by collecting fluids from an extended portion along the surface of a wellbore, which is likely to straddle one or more layers in laminated or fractured formations. Various designs and arrangements for use with a fluid tester, which may be part of a modular fluid tool, are disclosed in accordance with different embodiments.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to advance a geological formation probe with a surrounding pad to seal the pad against a borehole wall, to adjust the size of the area associated with a fluid flow inlet of the probe, where the size of the inlet area is selectably and incrementally variable, and to draw fluid into the fluid flow inlet by activating at least one pump coupled to at least one fluid passage in the probe.

Abstract: A downhole formation testing and sampling apparatus. The apparatus includes an expandable packer having a radially contracted running configuration and a radially expanded deployed configuration. At least one elongated sealing pad is operably associated with the expandable packer such that operating the expandable packer from the running configuration to the deployed configuration establishes a hydraulic connection between the at least one elongated sealing pad and the formation. The at least one elongated sealing pad has at least one opening establishing fluid communication between the formation and the interior of the apparatus. In addition, the at least one elongated sealing pad has an outer surface operable to seal a region along a surface of the formation to establish the hydraulic connection therewith. The at least one elongated sealing pad further has at least one recess operable to establish fluid flow from the formation to the at least one opening.

Abstract: In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sampled is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnet provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (e.g., without opening the sample chamber).

Abstract: In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sampled is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnet provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (e.g., without opening the sample chamber).

Abstract: Apparatus and methods for downhole formation testing including use of a probe having inner and outer channels adapted to collect or inject injecting fluids from or to a formation accessed by a borehole. The probe straddles one or more layers in laminated or fractured formations and uses the inner channels to collect fluid.

Abstract: The present invention relates to a method of detecting synthetic mud filtrate in a downhole fluid including placing a downhole tool into a wellbore, introducing a downhole fluid sample into the downhole tool, analyzing the downhole fluid sample in the downhole tool, producing at least two filtrate markers from the analyzing of the downhole fluid sample and converting the at least two filtrate markers by vector rotation to a sufficiently orthogonal signal. The first pumped fluid sample giving initial plateau readings can be a proxy for 100% drilling fluid having an initial orthogonal signal and subsequent samples can be converted to orthogonal signals that are referenced to the first pumped fluid signal to give a calculation of percent contamination of the formation fluid.

Abstract: In situ density and compressibility of a fluid sample are determined for a fluid sample collected downhole. The density and compressibility of the fluid sample is determined by measuring a distance to a piston contained within the sample chamber using an external magnetic field sensor that senses a magnetic field emanating from a magnetic provided on the piston internal to the sample chamber. The testing is performed quickly and at the surface in a noninvasive fashion (i.e., without opening the sample chamber).

Abstract: Apparatus and methods for downhole formation testing including use of a probe having inner and outer channels adapted to collect or inject injecting fluids from or to a formation accessed by a borehole. The probe straddles one or more layers in laminated or fractured formations and uses the inner channels to collect fluid.

Abstract: A downhole formation testing and sampling apparatus. The apparatus includes a setting assembly and an actuation module that is operable to apply an axial compressive force to the setting assembly shifting the setting assembly from a radially contracted running configuration to a radially expanded deployed configuration. A plurality of probes is coupled to the setting assembly. Each probe has a sealing pad with an outer surface operable to seal a region along a surface of the formation to establish the hydraulic connection therewith when the setting assembly is operated from the running configuration to the deployed configuration. Each sealing pad has at least one opening establishing fluid communication between the formation and the interior of the apparatus. In addition, each sealing pad has at least one recess operable to establish fluid flow from the formation to the at least one opening.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to measure formation fluid and obtain data, the data having measurement levels that vary over a parameter. The data is grouped in one or more categories, each category having data falling within a range, and the grouped data is analyzed as a function of the parameter. In some embodiments, the grouped data is used to identify at least one fluid type of the formation fluid using the grouped data.