Abstract: A fluid sampling tool and method for fluid sampling in an ultra-tight or tight formation. The tool may include a packer assembly that includes one or more inflatable packers and one or more exhaust ports, a multi-chamber section that includes one or more sample chambers, and at least two storage sections that each contain a storage tank, wherein each storage tank holds a stimulation fluid. A method for performing a stimulation operation that includes disposing a fluid sampling tool into a well, moving the fluid sampling tool to a zone of interest, and isolating the zone of interest with a packer assembly on the fluid sampling tool. The method may further include performing a first pressure draw down and a first pressure build up, performing an injectivity test, and performing a sampling process.

Abstract: A method includes providing a treatment fluid including a strong acid precursor defined by the structure: where X is independently selected from fluorine, chlorine, bromine, and iodine; where each of R1, R2, and R3 is independently selected from a hydrogen, X, and a C1 to C10 hydrocarbon chain; and where the electron withdrawing group (EWG) is independently selected from a carboxylic acid, carboxylate salt, or carboxylate ester, an orthoester, a sulfonic acid, sulfonate salt, or ester, a phosphonic acid, phosphonate salt, or phosphonate ester, a nitrate, or a cyanide; where Y is hydrogen, a cation, or a C1 to C10 hydrocarbon chain; and wherein each R? is independently is independently selected from a hydrogen, X, and a C1 to C10 hydrocarbon chain. The method also includes introducing the treatment fluid into a wellbore penetrating a subterranean formation.

Abstract: A model can be trained for discriminant analysis for substance classification and/or measuring calibration. One method includes interacting at least one sensor with one or more known substances, each sensor element being configured to detect a characteristic of the one or more known substances, generating an sensor response from each sensor element corresponding to each known substance, wherein each known substance corresponds to a known response stored in a database, and training a neural network to provide a discriminant analysis classification model for an unknown substance, the neural network using each sensor response as inputs and one or more substance types as outputs, and the outputs corresponding to the one or more known substances.

Abstract: Provided are compositions and methods that use a true crystallization temperature reduction additive in the aqueous internal phase. An example method may comprise providing an oil-based treatment fluid in the form of an invert emulsion comprising an aqueous internal phase and an oil external phase. The aqueous internal phase may include a bromide brine and a true crystallization temperature reduction additive, wherein the bromide brine has a density of about 14.2 lbs/gal or greater. The method may further include placing the oil-based treatment fluid into a wellbore.

Abstract: Apparatuses and methods for pressure regulating check valve assemblies are described. In an example, the check valve assembly comprises a housing defining a fluid passage having a fluid inlet side and a fluid outlet side. A lift check valve positioned within the fluid passage oriented to restrict fluid flow from the fluid inlet side and a second check valve positioned within the fluid passage oriented to restrict fluid flow from the fluid outlet side. A flow dampener is positioned within the fluid passage and between the first and second check valves.

Abstract: Downhole tool is provided that includes a body, an intake port for receiving fluid from external the body, a pump, a filtration device, and an exit port. The pump is in fluid communication with the intake port for withdrawing fluid through the intake port. The filtration device has a particulate removing filter, and a flow line extending from the intake port to the filtration device. The filtration device is contained within the body and is in fluid communication with the intake port. The exit port is in fluid communication with the filtration device for ejecting the fluid to external the body.

Abstract: A method comprises positioning a receiver in a borehole and determining an offset acoustic waveform at a target point. The method includes generating a reverse time sequence waveform of the determined offset acoustic waveform and generating, by a transmitter, an acoustic pulse based on the reverse time sequence waveform. The method includes detecting, by the receiver, an acoustic response to the acoustic pulse.

Abstract: The present disclosure provides a fixed-cutter drill bit including a bit body defining a bit rotational axis, a plurality of blades each having an inner end that is radially closer to the bit rotational axis than a remainder of the respective blade, a central bit surface, and a plurality of cutters disposed on the blades and including an innermost cutter located closest among all of the plurality of cutters to the bit rotational axis and having a flattened cutting surface, a cutting arc, and a relief having ends which is located within and interrupts the cutting arc such that the cutting arc includes at least two portions located on opposite ends of the relief. The disclosure also provides a drilling system including the drill bit and a drill string attached to the drill bit and a surface assembly to rotate the drill string and drill bit.

Abstract: A system includes a first plurality of pumps connected to draw from a clean fluid supply junction. A second plurality of pumps is operatively connected to a dirty fluid supply. A first valve is connected between the clean fluid supply junction and the dirty fluid supply for supplying clean fluid to the dirty fluid supply. A second valve is connected to feed a dirty fluid to the dirty fluid supply. A controller is operatively connected to the first and second valves and to the first and second pluralities of pumps for controlling downhole concentration and flow rate of proppant from the dirty fluid supply, wherein downhole concentration and flow rate are varied across a continuous spectrum.

Abstract: Fluid flow control devices and methods to reduce overspeed of a fluid flow control device are presented. A fluid flow control device includes a port and a rotatable component that rotates about an axis in response to fluid flow from the port. The fluid flow control device also includes a mechanical component disposed on the rotatable component and configured to reduce rotational speed of the rotatable component.

Abstract: A method and system for identifying a blind spot in one or more decoupled measurements. The method may comprise disposing an electromagnetic well measurement system into a wellbore. The electromagnetic well measurement system comprise an electromagnetic transmitter and a plurality of electromagnetic receivers. The method may further comprise transmitting electromagnetic fields into a formation with the electromagnetic transmitter, measuring the electromagnetic fields with the plurality of electromagnetic receivers as one or more measurements at one or more depths in the wellbore, decoupling the one or more measurements to form decoupled measurements, identifying if a blind spot is in the decoupled measurements, and performing an inversion with the decoupled measurements.

Abstract: A cement composition can include water; cement, wherein less than 75 w/w % of the total amount of the cement is Portland cement; and a fluid loss additive, wherein the fluid loss additive comprises a polymer network having at least one branching point formed with a monomer and a cross-linking agent that comprises at least three active functional groups. The cement can also be a non-Portland cement. The monomer can be a vinyl ester-based monomer that is polymerized with the cross-linking agent to form the polymer network. The cement composition can be used in an oil and gas operation.

Abstract: Methods of capturing carbon dioxide in a wellbore can include installing a sealing element in the wellbore. The sealing element swells in the presence of carbon dioxide and can be used for capturing the carbon. The sealing element can include a carbon-swelling material, such as a carbon-swelling polymers, metal-based materials, or combinations of elastomeric polymers and metal-based materials. The sealing element can also include combinations of different carbon-swelling materials, fillers or other compounds, and materials that are not carbon swellable. The sealing element can create a seal, form an anchor, or create a seal and form an anchor in the wellbore after swelling.

Abstract: A nuclear magnetic resonance (NMR) downhole tool and method that may include a housing, a power source, a Radio Frequency (RF) pulse generator tank electrically connected to the power source, a power switch electrically disposed within the RF pulse generator tank and disposed in the housing, and an NMR signal acquisition tank electrically connected to the RF pulse generator tank and disposed in the housing. The method may include disposing the NMR downhole tool into a wellbore, charging a first capacitor with the power source that is electrically connected to the first capacitor, generating a RF pulse, disconnecting the first capacitor from the RF pulse generator tank, and storing energy from the inductive coil in the first capacitor. The method may further include connecting the inductive coil to an NMR signal acquisition tank using a decoupler switch and acquiring an NMR signal with the NMR signal acquisition tank.

Abstract: A method may include: introducing a treatment fluid into a stream, the treatment fluid comprising: a base fluid and a supramolecular host guest product, wherein the supramolecular host guest product comprises a treatment fluid additive and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive.

Abstract: A system for an adjustably flexible downhole tool includes first and second connector ends each configured to connect to adjacent downhole tools and a shaft extending between the first and second connector ends. The shaft is configured to bend in response to passing through curved portions of a wellbore. The adjustably flexible downhole tool also includes an outer sleeve disposed around at least a portion of the shaft and extending from the first connector end in a direction toward the second connector end and at least one adjustable member configured to move axially, with respect to the shaft, from a first position to a second position to increase bending stiffness and/or torsional stiffness of the adjustably flexible downhole tool. The at least one adjustable member at least partially restrains bending of the shaft in the second position.

Abstract: Surfactant compositions and methods for hydrocarbon recovery from a subterranean formation are provided. In some embodiments, the methods include: introducing a surfactant composition comprising an aqueous phase, an oil phase, an organic solvent, and one or more surfactants into a wellbore penetrating at least a portion of a subterranean formation; introducing an organic compound comprising a phosphonoalkyl moiety into the wellbore; and at least partially displacing a hydrocarbon from the subterranean formation by contacting a surface in the subterranean formation with the surfactant composition or the organic compound. In some embodiments, the compositions include: an aqueous phase; an oil phase comprising at least one solvent; an organic solvent; one or more surfactants; and at least one organic compound comprising a phosphonoalkyl moiety.

Abstract: A tubular string includes a first tubular member with a pin end with pin threads and a pin external load shoulder. The tubular string also includes a second tubular member with a box end with a box external load shoulder and box threads, the pin threads being threadable into the box threads to form a connection, wherein the pin external load shoulder has an outer diameter (OD) that is different than an OD of the box external load shoulder. A load distribution sleeve is locatable between the first and second tubular members when threaded together and includes a first end facing the first tubular member and a second end facing the second tubular member, wherein the ODs of the load distribution sleeve first and second ends match the ODs of the pin and box external load shoulders respectively. The load distribution sleeve contacts the pin and box external load shoulders and distributes a make-up load between the pin and box external load shoulders when the connection is made up.

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: Provided is an electrically surface-controlled subsurface safety valve (ESCSSV). The ESCSSV, in one example, includes an outer housing comprising a central bore extending axially through the housing that is configured to convey production fluids there through. The ESCSSV, in this embodiment, further includes a valve closure mechanism disposed proximate a downhole end of the central bore, and a bore flow management actuator disposed in the central bore and configured to move between a closed state and a flow state to engage or disengage the valve closure mechanism to determine a flow condition of the production fluids through the central bore. The ESCSSV, in this embodiment, additionally includes an electric valve assembly fluidically coupled to the bore flow management actuator and configured to select between a section pressure or the annulus pressure to control the bore flow management actuator and determine the flow condition of production fluids through the central bore.