Abstract: A method for inhibiting the formation, deposition and adherence of scale to metallic and other surfaces in the equipment, vessels and/or piping of facilities for the handling of oil and gas produced fluid is disclosed. An effective scale inhibiting amount of alginate is added to a produced fluid containing a scale-forming divalent cation. The alginate effectively cross-links with a scale-forming divalent cation, e.g., calcium, forming an alginate gel for subsequent separation and removal from the produced fluid.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a non-polar oil, —OH, —(OH)2, or —(OH)3 alcohol, water, and an emulsifier in proportional amounts by weight or volume in that order. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity or viscosity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit and a method of electrocrushing drilling.

Abstract: The present disclosure provides adjustable mandrel hanger assemblies and methods of their use. The adjustable mandrel hanger assembly includes an upper wellhead component, a lower wellhead component comprising a load shoulder, a mandrel hanger with a protrusion disposed on an exterior of the mandrel hanger, a seal assembly, and a height adjustment ring, wherein the height adjustment ring fits securely around a protrusion of the mandrel hanger and wherein a largest exterior diameter of the height adjustment ring is greater than an interior diameter of the load shoulder.

Abstract: A system for developing multiple subterranean wellbores in a land-based field can include a first operational platform disposed over a first entry point of a first subterranean wellbore at a first time. The system can also include a second operational platform disposed over a second entry point of a second subterranean wellbore at the first time, where the first entry point and the second entry point are located proximate to each other. The system can further include first field equipment disposed on the first operational platform. The system can also include a second field equipment disposed on the second operational platform. The first field equipment can be used to develop the first subterranean wellbore, and the second field equipment can be used to develop the second subterranean wellbore.

Abstract: The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a polar oil, a non-polar oil, or a combination thereof and glycerine carbonate. The electrocrushing drilling fluid or base fluid may further include water or glycerin. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit.

Abstract: Provided herein are liquid polymer (LP) compositions comprising a synthetic (co)polymer (e.g., an acrylamide (co)polymer), as well as methods for preparing inverted polymer solutions by inverting these LP compositions in an aqueous fluid. The resulting inverted polymer solutions can have a concentration of a synthetic (co)polymer (e.g., an acrylamide (co)polymer) of from 50 to 15,000 ppm, and a filter ratio of 1.5 or less at 15 psi using a 1.2 ?m filter. Also provided are methods of using these inverted polymer solutions in oil and gas operations, including enhanced oil recovery.

Abstract: A pulsed sinusoidal acoustic signal transmitted through a subsurface volume of a wellbore may be detected. A time-reversed acoustic signal of the pulsed sinusoidal acoustic signal may be transmitted through the subsurface volume of the wellbore. Transmission of the time-reversed acoustic signal through the subsurface volume of the wellbore may result in generation of focused acoustic signal in the subsurface volume of the wellbore. The focused acoustic signal in the subsurface volume of the wellbore may be detected, and the integrity of the wellbore may be determined based on the focused acoustic signal in the subsurface volume of the wellbore.

Abstract: The present invention relates generally to systems and processes for improved drag reduction estimation and measurement and more specifically to portable drag reduction analyzers and processes for upscaling drag reduction data for a variety of field applications. A drag reduction parameter AB for the fluid mixture is used for determining drag reduction for a fluid mixture in an oil field or pipeline operation.

Abstract: A graphical user interface may provide visualization of comparison between planned value(s) and usage value(s) of a set of operating parameters for a tool. The graphical user interface may include a planned usage region and a usage region. The planned usage region may provide visualization of the planned value(s) for the tool. The usage region may provide visualization of the usage value(s) for the tool. The usage region may include a compliance section. The compliance section may provide visualization of whether the usage value(s) complies with the corresponding planned value(s) such that the compliance section includes different visual features based on whether the usage value(s) complies or does not comply with the corresponding planned value(s). The usage region may provide comments and/or recommendations based on the learnings from analysis of offset wells.

Abstract: A method is described for seismic modeling implemented on a computer system including multiple computer nodes, which includes receiving, at a computer processor, a 4D speed of sound in water library and a marine seismic survey geometry; creating, via the computer processor, a full survey 3D Earth model for each seismic shot time based on the 4D speed of sound in water library to generate a set of dynamic 3D Earth models; simulating 4D seismic shots for the set of dynamic 3D Earth models by simulating multiple shots on each node to generate a set of 4D seismic shot gathers; and outputting the 4D seismic shot gathers.

Abstract: Apparatus (10) and methods for combining time reversal and elastic nonlinearity of formation materials for qualtitatively probing for over-pressured regions down hole in advance of a well drilling bit, to determine the distance to the over-pressured region, and for accurately measuring pore pressure downhole in a formation, are described. Classical and reciprocal time reversal methods may be utilized to achieve these measurements.

Abstract: A disclosed pulsed-power drilling system may include a controller that receives and analyzes feedback from downhole components reflecting changing conditions or performance measurements associated with a pulsed drilling operation to determine that an operating parameter of the drilling operation should be modified. The controller may output a control signal to cause an adjustment of a configurable downhole component, such as mechanical, electrical, or hydraulic component that affects the operating parameter, while the drill bit remains in the wellbore. The controller may adjust a segmented transformer of a pulse-generating circuit, changing the number of primary winding switches that are fired, or the timing of the firing of the switches, to modify characteristics of the generated pulses. Adjusting a downhole component may affect the drilling rate, the drilling direction, the flow of drilling fluid, a pulse rise time, a pulse repetition rate, or a rate of penetration for the drilling operation.

Abstract: Pullout information for a drilling tool may be obtained. The pullout information may characterize one or more operating characteristics of the drilling tool during pullout of the drilling tool from the wellbore. A pullout friction factor for the wellbore may be determined based on the pullout information. A comparison of the pullout friction factor to a pullout friction factor threshold may be performed to determine whether the pullout friction factor satisfies or violates the pullout friction factor threshold. The condition of the wellbore to run the casing into the wellbore may be determined based on whether the pullout friction factor satisfies or violates the pullout friction factor threshold.

Abstract: Embodiments of categorizing fractures in a subsurface formation are provided herein. One embodiment comprises obtaining at least one borehole image for a plurality of fractures in a subsurface formation and at least one resistivity log for the plurality of fractures of the surface formation. The embodiment comprises determining first aperture data based on the at least one borehole image for the plurality of fractures and determining second aperture data based on the at the least one resistivity log for the plurality of fractures. The embodiment comprises comparing the first aperture data based on the at least one borehole image and the second aperture data based on at least one resistivity log to determine whether to categorize each fracture of the plurality of fractures as a naturally occurring fracture or a non-naturally occurring fracture. The embodiment comprises generating an output indicating the categorization of each fracture and displaying the output.

Abstract: Disclosed are systems and methods for thermal management of subsea conduits. A jumper that carries oil and/or gas produced from a subsea well in a subsea production facility located on a seabed has a first end for connecting to a first subsea component and a second end for connecting to a second subsea component. The jumper includes a jumper segment that is sloped relative to the horizontal, such that gravity assists with drainage of fluid from the second end of the jumper independent from fluid pressure in the jumper. At least a portion of the jumper is uninsulated to allow exchange of heat with seawater surrounding the jumper as produced fluid travels through the jumper. The amount of insulation on the jumper can be varied such that heat transfer from the production fluids to seawater surrounding the jumper circuit is adjusted as desired.

Abstract: Disclosed are systems and methods for thermal management of subsea interconnecting conduit such as jumpers that provide cooling and heat retention of production fluids within the jumpers. In a jumper circuit, parallel sections of jumper are provided having differing amounts of heat transfer between surrounding seawater and production fluids flowing within. Valving is provided to control fluid flow between the parallel sections of jumper, thus controlling the amount of heat transfer between the surrounding seawater and the jumper circuit. A control system can be used to generate an alarm based on fluid temperature and/or fluid flow rate within the jumper circuit indicating the need to adjust the valving to manage the temperature of fluids within the jumper circuit. Changes may be needed particularly depending on the phase of production, e.g., early life, normal operation, shut down and late life operation.

Abstract: Disclosed are systems and methods for thermal management of subsea conduits such as jumpers that provide the ability to alternate between cooling and heat retention of production fluids within the conduit as needed depending on the phase of operation. Adjustable insulation elements are provided on the conduits so that convective heat transfer between surrounding seawater and the conduit can be allowed or reduced. A control system can activate an alarm indicating the need to adjust the insulation depending on the temperature and/or flow rate of fluids in the conduit. Conventional conduits can be retrofitted by adding adjustable insulation elements to enable thermal management.

Abstract: Disclosed are systems and methods for thermal management of subsea jumpers that provide the ability to cool and/or retain heat in production fluids within the jumpers. The jumpers are provided with an annular pipe section surrounding the jumper circumferentially. The flow of a liquid cooling medium into an inlet and out an outlet of the annular pipe section can be controlled to provide cooling or heat retention as needed. A control system can be used to generate an alarm based on fluid temperature and/or fluid flow rate within the jumper indicating the need to adjust the flow of the cooling medium to manage the temperature of fluids within the jumper. Changes may be needed particularly depending on the phase of production, e.g., early life, normal operation, shut down and late life operation.

Abstract: An improved nozzle device for a down-flow hydroprocessing reactor is disclosed. The down-flow nozzle is useful in the petroleum and chemical processing industries in catalytic reactions of hydrocarbon feedstocks in the presence of hydrogen, at an elevated temperature and pressure, to provide for the mixing and distribution of gas and liquid to reactor catalyst beds. Typical hydroprocessing applications include hydrotreating, hydrofinishing, hydrocracking and hydrodewaxing.

Abstract: A subterranean coring assembly can include a body having at least one wall that forms a cavity, wherein the cavity has a top end and a bottom end. The subterranean coring assembly can also include a first flow regulating device movably disposed within the cavity, where the first flow regulating device is configured to move from a first default position to a first position within the cavity based on first flow characteristics of fluid that flows into the top end of the cavity toward the bottom end of the cavity.