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 swellable packer assembly that includes a mandrel, a sealing element disposed about a least a portion of the mandrel, and a degradable metal coating disposed about at least a portion of an outer surface of the sealing element. The degradable metal coating fluidly isolates the portion of an outer surface of the sealing element from an exterior of the coating and the sealing element is formed of a material responsive to exposure to a fluid in a wellbore to radially expand from the mandrel. The degradable metal coating is selectively removable from the mandrel downhole so as to expose the sealing element to the fluid in the wellbore.

Abstract: A method may include: introducing a silane based aqueous soluble resin into a wellbore, wherein the silane based aqueous soluble resin comprises a glycidyl alkoxy silane containing resin and an amino alkoxy silane hardener. The silane based aqueous soluble resin may include 3-glycidoxypropyl trimethoxy silane and n-(3-(trimethoxysilyl)propyl)ethylenediamine.

Abstract: A method for determining discharge area in hydraulic stimulation operations is provided that includes obtaining one or more treatment data inputs from a well system, and determining a discharge area by applying the one or more treatment data inputs to a function that determines discharge area in terms of volumetric flow rate of the fracturing fluid, wherein the discharge area is a total area of all downhole exits through which the fracturing fluid exits a wellbore into a subterranean formation.

Abstract: A fiber optic sensing (FOS) system and method. The system may include one or more interrogator units and a proximal wavelength division multiplexer (WDM) and a distal WDM optically connectable to the one or more interrogator units, an upgoing transmission fiber, a down-going transmission fiber, and one or more downhole sensing fibers. The method may include transmitting one or more light pulses from an interrogator unit, multiplexing the one or more light pulses from the interrogator unit with a proximal WDM into an upgoing transmission fiber and a down-going transmission fiber, and receiving the one or more light pulses with a distal WDM. The method may further include multiplexing the one or more light pulses from the upgoing transmission fiber and the down-going transmission fiber into one or more downhole sensing fibers and receiving backscatter light from at least one of the one or more downhole sensing fibers.

Abstract: A method for removing a guided wave noise in a time-domain may include recording one or more acoustic signals with one or more receivers at a first location, wherein the one or more acoustic signals are raw data. The method may further include determining a slowness range, estimating a downward guided wave noise by stacking the one or more acoustic signals based at least in part on a positive slowness, estimating an upward guided wave noise by stacking the one or more acoustic signals based at least in part on a negative slowness, and identifying a dominant direction of propagation. The method may further include identifying a slowness from a highest stacked amplitude for the dominant direction of propagation, estimating a downward guided wave noise with the slowness, estimating an upward guided wave noise with the slowness, and subtracting the downward guided wave noise and the upward guided wave noise.

Abstract: The disclosure provides a packing monitor, method, and gravel pack system for real-time monitoring of a particulate for improved gravel packing. Via the real-time monitoring, the quality of the gravel pack can be detected in real-time. Accordingly, a top-off procedure can be performed without additional tripping of the inner service tool string. Detecting when the gravel pack is approaching screen-out can also be determined in real-time. Detecting when screen-out is approaching allows the operator to prepare to stop pumping in case of miscalculations or early screen-out. In one example, the packing monitor includes: (1) a packing detector configured to, when stationary within the wellbore, obtain measurements indicating presence of a particulate in an annulus of the wellbore at different positions along a length of a screen; and (2) a packing controller configured to determine, based on the measurements, a status of the particulate in the annulus at the different positions.

Abstract: A drilling system can be used to drill a borehole. The drilling system may include a first housing defining a main fluid flow path and a second housing defining a bypass flow path toward an annulus of a wellbore. A flow control choke may be positioned between the first housing and the second housing. The flow control choke may include a rotatable section and a stationary section that is stationary relative to the rotatable section. The stationary section may have a curved interface with the rotatable section for restricting a flow of a drilling fluid through the bypass flow path.

Abstract: A method of designing a cement slurry may include: (a) selecting a target permeability and a density requirement; (b) inputting the target permeability into a permeability model and generating a proposed cement composition using the permeability model, wherein the proposed cement composition comprises at least a cement and concentration thereof, and a water and concentration thereof such that a cement slurry formed from the proposed cement composition water meet the density requirement; (c) preparing the cement slurry based on the proposed cement composition; and (d) introducing the cement slurry into a wellbore and allowing the cement slurry to set to form a hardened cement.

Abstract: A method and system for generating an acoustic log. The method may comprise disposing an acoustic logging tool in a wellbore, broadcasting a shaped signal with the acoustic logging tool such that the shaped signal interacts with a boundary of a casing and a material, recording a result signal from the boundary with the acoustic logging tool, and decomposing the result signal into a resonance mode. The method may further comprise applying a bandpass filter to the resonance mode to form a filtered signal, selecting a baseline signal from the filtered signal, removing the baseline signal from the filtered signal, and generating a log from the filtered signal. The system may comprise an acoustic logging tool. The acoustic logging tool may comprise at least one transmitter and at least one receiver. The system may further comprise a conveyance and an information handling system communicatively connected to the acoustic logging tool.

Abstract: A system can include a filter assembly with a filter and a substance in the filter assembly, and at least one optical computing device having an integrated computational element which receives electromagnetic radiation from the substance. A method can include receiving electromagnetic radiation from a substance in a filter assembly, the electromagnetic radiation from the substance being received by at least one optical computing device having an integrated computational element, and the receiving being performed while a filter is positioned in the filter assembly. A detector may receive electromagnetic radiation from the integrated computational element and produce an output correlated to a characteristic of the substance. A mitigation technique may be selected, based on the detector output.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a borehole correction factor for determining a true resistivity by selecting a model to apply in identifying the borehole correction factor and applying the model to an apparent resistivity to identify the borehole correction factor. To perform borehole correction, a multiplicative coefficient is needed to apply to the apparent resistivity. A database of this multiplicative coefficient, called the borehole correction factor, is generated based on the borehole correction model. The technology described herein allows operators to avoid time-consuming variable borehole diameter sweeps and complex borehole diameter inversion current used in resistivity logging software.

Abstract: A detonator housing facilitates assembly of detonator components of a perforating gun. In an example, the detonator housing comprises a housing body configured for coupling to a charge tube of a perforating gun. A detonator receptacle is formed on the housing body for receiving a detonator. A detonating cord receptacle is formed on the housing body adjacent the detonator receptacle for receiving an end portion of a detonating cord in an overlapping relationship with the detonator. A detonating cord stop is formed on the detonating cord receptacle to limit an insertion depth of the detonating cord within the detonating cord receptacle.

Abstract: Provided is a wellbore scraper assembly for use with a wireline. The wellbore scraper assembly, in one example, includes a tubular housing, a plurality of hydraulically deployable scraper features associated with the tubular housing, the plurality of hydraulically deployable scraper features configured to move from a first retracted state to a second radially extended state, and a hydraulic deployment system coupled to the plurality of hydraulically deployable scraper features, the hydraulic deployment system configured to move the plurality of hydraulically deployable scraper features from the first state to the second state.

Abstract: Provided are methods and systems related to spacer fluids that include a spacer additive comprising a biopolymer polysaccharide gum, a modified cellulose, and a solid scouring material while being essentially free of clay and crystalline silica. These spacer fluids have improved compatibility with displaced fluids, such as oil-based drilling fluids. In addition, the combination of the biopolymer polysaccharide gum and modified cellulose imparts unique rheological characteristics to the spacer fluid as compared to the use of either of these materials alone.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job.

Abstract: Noise in drilling operation measurements can be eliminated or reduced using machine learning. For example, a system described herein can receive one or more measured signals in a logging-while-drilling process for drilling a wellbore. The system can determine a coupling factor for noise in the one or more measured signals. The system can generate a corrected signal by removing the noise multiplied by the coupling factor from the one or more measured signals. The system can output the corrected signal for use in drilling operations in the wellbore.

Abstract: Various embodiments include apparatus and methods implemented to take into consideration gauge length in optical measurements. In an embodiment, systems and methods are implemented to interrogate an optical fiber disposed in a wellbore, where the optical fiber is subjected to seismic waves, and to generate a seismic wavefield free of gauge length effect and/or to generate a prediction of a seismic wavefield of arbitrary gauge length, based on attenuation factors of a plurality of wavefields acquired from interrogating the optical fiber. In an embodiment, systems and methods are implemented to interrogate an optical fiber disposed in a wellbore, where the optical fiber is subjected to seismic waves, and to convert a seismic wavefield associated with a first gauge length to a seismic wavefield associated with a different gauge length that is a multiple of the first gauge length. Additional apparatus, systems, and methods are disclosed.

Abstract: A system includes a first wellbore operation controller for controlling a wellbore operation and generating a first broadcast indicating a first data topic desired for controlling the wellbore operation. The system also includes a second wellbore operation controller for generating a data stream associated with a wellbore and for generating a second broadcast indicating a second data topic that promotes the data stream. The system includes a mediator computing device that receives the first broadcast and the second broadcast and determines that the first wellbore operation controller is subscribed to the data stream by comparing the first data topic to the second data topic. In response to determining that the first wellbore operation controller is subscribed to the data stream, the mediator computing device creates a data link between the first wellbore operation controller and the second wellbore operation controller.

Abstract: An ingress-barrier assembly for use with pressure-operated downhole equipment can be used to limit hydraulic fluid flow in a wellbore environment for completions and operations through the life of a well. An assembly can comprise a first port to communicate hydraulic fluid with a first fluid conveyance line. The assembly can include a second port to communicate hydraulic fluid with a second fluid conveyance line. The assembly can further include a first-end stop, a second-end stop, and a moveable seal. The moveable seal can move within a bore of the assembly between the first-end stop and the second-end stop to communicate pressure between the first port and the second port.