Abstract: Systems, methods, and apparatuses of the present disclosure generally relate to dissolvable plugs for separating fluids in a wellbore. A dissolvable plug includes a first end comprising a first fluid barrier. The first fluid barrier includes a polymer film. The dissolvable plug also includes a second end opposite to the first end. The second end comprises a second fluid barrier. The second fluid barrier comprises a polymer film. The dissolvable plug includes a solid structure made of a sand and salt mixture.

Abstract: A solid-state hydrophone may include a piezoelectric rod positioned between at least two electrodes. The piezoelectric rod may be disposed within a metallic housing to shield the piezoelectric rod and its connections from acoustic and electromagnetic waves. The piezoelectric rod and the electrodes may be potted in the mechanical housing using a potting material that may be positioned adjacent to the piezoelectric rod. At least a layer of the potting material may be positioned between the piezoelectric rod and the metallic housing to physically separate the piezoelectric rod from the metallic housing.

Abstract: Methods, systems, and program products are disclosed for implementing acoustic logging and determining wellbore material characteristics. In some embodiments, a method may include determining a polar differential signal for each of one or more pairs of azimuthally offset acoustic measurements within a wellbore. A reference azimuth is identified based, at least in part, on comparing the polar differential signals to a modeled bonding differential signal within a target response window. The method further includes determining differences between an acoustic measurement at the reference azimuth and acoustic measurements at one or more other azimuths and determining a wellbore material condition based, at least in part, on the determined differences.

Abstract: An acoustic logging tool may comprise a center load carrying pipe, a receiver module connected to the center load carrying pipe, one or more transmitter modules connected to the center load carrying pipe, and one or more mass modules connected to the center load carrying pipe.

Abstract: A breaker composition comprising (i) a first acid precursor, (ii) a second acid precursor and (iii) an aqueous fluid wherein the first acid precursor has an effective operating temperature of from about 15° C. to about 120° C. and the second acid precursor has an effective operating temperature of from about 30° C. to about 180° C.

Abstract: Provided is a method for mitigating a lost circulation zone. The method may include providing a lost circulation treatment composition that may include an acid responsive polymer that may include at least one monomer, at least one comonomer, and at least one crosslinker; a carbonate-based solvent; and a carrier fluid that may include water. The method may also include introducing the lost circulation treatment composition into a wellbore within a subterranean formation, wherein the subterranean formation may include the lost circulation zone; placing the lost circulation treatment composition into the lost circulation zone, hydrolyzing the carbonate-based solvent to generate carbon dioxide, and causing the swelling (change of shape) of acid responsive polymer to mitigate the losses.

Abstract: Waves from cement bond logging with a sonic logging-while-drilling tool (LWD-CBL) are often contaminated with tool waves and may yield biased CBL amplitudes. The disclosed LWD-CBL wave processing corrects the first echo amplitudes of LWD-CBL before calculating the BI. The LWD-CBL wave processing calculates a tool wave amplitude and a phase angle difference as the difference of the phases between the tool waves and casing waves. The tool waves are then used to correct the LWD-CBL casing wave amplitude and remove errors introduced from tool waves. In conjunction with the sets of operations described, the LWD-CBL wave processing also include array preprocessing operations. Array preprocessing may employ variation of bandpass filtering and frequency-wavenumber (F-K) filtering operations to suppress tool wave.

Abstract: A flow control system for a well includes a primary safety valve and a secondary safety valve disposable within a valve body of the primary safety valve. The secondary safety valve may include a control line port for receiving control fluid pressure from the same control line as the primary safety valve. A choke in fluid communication with the control line port delays a closing of the secondary safety valve relative to a closing of the primary safety valve in response to a decrease in the control fluid pressure.

Abstract: A subsurface safety valve assembly that includes a valve housing comprising a valve seat with a circumference and a seat seal surface. The valve assembly also includes a flapper rotatably connected to the valve housing and comprising a flapper seal surface. The flapper is rotatable into sealing engagement with the seat seal surface in a closed position to form a circumferential surface-to-surface seal. The valve assembly also includes a dovetail groove cut into the seat seal surface or the flapper seal surface and a seal ring held within the dovetail groove and positioned to form a seal against the seal ring when the flapper is in the closed position. The seat seal surface, the flapper seal surface, the dovetail groove, and the seal ring are shaped such that the load on the seal ring is uniform around the seal ring when the flapper is in the closed position.

Abstract: Systems and methods of the present disclosure relate to protecting a control line as it passes through a junction in a downhole environment. A retractable transition joint (RTJ) comprises at least two members. A first member is operable to retract into a second member. A tubular extends through the first and second members. The tubular comprises a distal end that is removably attached to a distal end of the second member. The first and second members are operable to receive the control line.

Abstract: The present disclosure may relate to a method of remediating a wellbore. The method may comprise pumping a resin treatment fluid from a surface location to an annular space bounded by an outer diameter of a production tubular, wherein the resin treatment fluid comprises a liquid hardenable resin, a hardening agent, and a particulate bridging agent. The resin treatment fluid may gravity settle in the annular space to contact production equipment in the annular space such that at least a portion of the particulate bridging agent bridges across one or more damaged sections of the production equipment, wherein at least a portion of the liquid hardenable resin sets to form a hardened mass to seal the one or more damaged sections.

Abstract: A method and system for performing a pressure test. The method may comprise inserting a formation testing tool into a wellbore to a first location within the wellbore, identifying one or more tool parameters of the formation testing tool, performing a first pre-test with the pressure transducer when the pressure has stabilized to identify formation parameters, inputting the formation parameters and the one or more tool parameters into a forward model, changing the one or more tool parameters to a second set of tool parameters; performing a second pre-test with the second set of tool parameters; and comparing the first pre-test to the second pre-test. A system may comprise at least one probe, a pump disposed within the formation testing tool, at least one stabilizer, a pressure transducer disposed at least partially in the at least one fluid passageway, and an information handling system.

Abstract: Aspects of the subject technology relate to systems and methods for determining cement barrier quality of a cementing process. Systems and methods are provided for receiving data from a distributed acoustic sensing fiber optic line positioned proximate to cement barrier of a wellbore, determining at least one zonal isolation in the cement barrier based on the data received from the distributed acoustic sensing fiber optic line, and compiling a cement bond log based on the determining of the at least one zonal isolation in the cement barrier.

Abstract: A downhole motor or pump assembly that includes a housing that includes a metal. A stator that includes an elastomer compound with an uncured plasticizer is secured and sealed within the housing using an adhesive system that includes an adhesive and a dried film thickness of 2.5 mil to 7 mil. The assembly also includes a rotor rotatable within the stator. The motor or pump is operable by rotation of the rotor within the stator. In the case of a motor assembly, the motor assembly may be part of a drilling assembly that includes a drillstring and a drill bit to drill a borehole.

Abstract: A cutting element includes a substrate configured to couple to a pocket formed in a blade of a downhole drill bit and a polycrystalline diamond portion secured to the substrate. The polycrystalline diamond portion includes a cutting face, a radial sidewall, and a cutting edge formed at a transition from the radial sidewall to the axial the cutting face. The cutting face includes a plow feature disposed at a center of the cutting face. The plow feature has a face portion and a shoulder portion. The shoulder portion extends radially outward from the face portion and axially downward toward the substrate. Additionally, the cutting face includes a recessed portion extending between the cutting edge and a radially outer edge of the shoulder portion.

Abstract: Methods and systems for removing tool mode waveforms. The method may include disposing a bottom hole assembly (BHA) into a wellbore. The BHA may comprise at least one transmitter configured to transmit a pressure pulse and at least one receiver configured to record one or more waveforms. The method may further comprise performing a logging-while-drilling (LWD) operation in which the one or more waveforms are recorded with the at least one receiver, transmitting the one or more waveforms to an information handling system, removing one or more tool mode waveforms from the one or more waveforms to form an updated set of waveforms, and forming differential phase time semblance map based at least in part on the updated set of waveforms. The system may comprise the BHA and information handling system configured to remove one or more tool mode waveforms.

Abstract: The disclosure provides for a layered metal with resistance to hydrogen induced cracking and method of production thereof, comprising a core metal alloy and a skin metal alloy. The core metal alloy comprises twinned boundaries. The core metal alloy has undergone plastic deformation and a heat treatment. The core metal alloy comprises nickel and cobalt. The skin metal alloy is disposed on the core metal alloy, wherein the skin metal alloy comprises an entropy greater than the core metal alloy. The core metal alloy comprises a greater density of twinned boundaries than the skin metal alloy. The skin metal alloy comprises a stacking fault energy of at least about 50 mJ/m2, and the skin metal alloy comprises iron, aluminum, and boron.

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: Systems and methods for harvesting geothermal energy use temperature-based flow control to optimize the extraction of thermal energy from a geothermal reservoir. In one example, a thermal transport fluid is flowed into a wellbore traversing a thermal reservoir of a formation. Flow of the thermal transport fluid into and out of the thermal reservoir is dynamically controlled at each of a plurality of injection and/or return locations in response to a downhole parameter such as temperature. For example, flow may be controlled so that the flow into the thermal reservoir is greater at the injection locations where the temperature is hotter and that the flow out of the thermal reservoir is greater at the return locations where the temperature is hotter. The thermal transport fluid produced from the return locations is then conveyed to surface to extra the thermal energy.

Abstract: An acoustic isolator and methods to the same. The acoustic isolator may comprise a body, one or more annular chambers formed inside the body of the acoustic isolator and positioned along a longitudinal axis of the acoustic isolator, an annular groove formed on an outer surface of the body of the acoustic isolator, and a passage disposed between the one or more annular chambers and the annular groove. The method may comprise transmitting an acoustic wave from a transmitter disposed on an acoustic logging tool into a subterranean formation, receiving an acoustic signal from the subterranean formation with a receiver disposed on the acoustic logging tool, and attenuating a second acoustic wave that moves between the transmitter and the receiver and through an acoustic isolator.