Abstract: A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200° C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).

Abstract: A system for remediating a blockage in a subsea a subsea fluid system includes a hot tap system connected to an outer surface of a subsea fluid conduit of the subsea fluid system, a first flowpath extending from a fluid source, through the first coiled tubing and the hot tap system, and into the subsea fluid conduit, and a second flowpath extending from the subsea fluid conduit and through the hot tap system, wherein the second flowpath is separate from the first flowpath, wherein the hot tap system is configured to inject a first fluid into the subsea fluid conduit along the first flowpath and receive a second fluid from the subsea fluid conduit along the second flowpath.

Abstract: A hot tap assembly for accessing a subsea fluid system includes a landing structure configured to releasably attach to a subsea fluid conduit of the subsea fluid system, a clamp assembly positionable on the landing structure, where in the clamp assembly includes a hot tap clamp including a first jaw and a second jaw, wherein a first annular seal assembly and a second annular seal assembly are disposed on an engagement surface of the second jaw, and a drill assembly positionable on the landing structure, wherein the drill assembly includes a drill disposed in a central conduit that is insertable through a central passage formed in the second jaw of the clamp assembly, wherein the hot tap clamp is configured to actuate between an open position configured to receive the subsea fluid conduit and a closed position configured to sealingly engage the subsea fluid conduit with the first seal assembly and the second seal assembly of the clamp assembly.

Abstract: A hydrocarbon production system includes a well at a remote location. The well is configured to produce hydrocarbon production fluids comprising natural gas. The system also includes a turbo-generator coupled to the well and configured to receive the natural gas and produce electricity from the natural gas. In addition, the system includes a high performance computing (HPC) data center coupled to the turbo-generator and configured to be powered by the electricity from the turbo-generator.

Abstract: A method comprises correlating—in a system which comprises a non-aqueous phase comprising a hydrocarbon fluid, and an aqueous phase—partitioning levels of a basic contaminant and/or an acid of interest into the aqueous phase with the pH of the aqueous phase. The partitioning levels of the basic contaminant and the acid of interest, as well as the pH of the aqueous phase, are obtained under conditions which are representative of those used in a partitioning process in which a basic contaminant is removed from a hydrocarbon fluid. The correlations may be used in a method for selecting an acidic environment for use in a partitioning process, for estimating corrosion risk downstream of a partitioning process, or for controlling a partitioning process.

Abstract: A method for performing an inspection includes (a) concurrently viewing a real object through a display screen of a head-worn display device worn by a user and a virtual object projected on the display screen of the head-worn display device. In addition, the method includes (b) comparing the virtual object to the real object. Further, the method includes (c) generating an inspection result in response to the comparison in (b).

Abstract: A technique for estimating a depth of investigation of a seismic survey includes in various aspects a method and an apparatus. The method is for use in seismic exploration and includes: forward modeling on a subsurface attribute model of a subterranean region to generate a set of low frequency seismic data, the subsurface attribute model being generated from data representative of the subterranean region; performing a reverse time migration on the low frequency seismic data to obtain a plurality of gathers with large opening angles; stacking the gathers to yield a diving wave illumination image; and estimating a full-waveform inversion depth of investigation from the diving wave illumination image. The apparatus may include a computing apparatus programmed to perform the method and/or a program storage medium encoded with computing instructions that, when executed, perform the method.

Abstract: A method for use in seismic exploration includes: obtaining a diving wave illumination image of a subterranean region from a set of seismic data representative of the subterranean region using a selected acquisition geometry; clipping an inverse of the diving wave illumination image to a range of values; and performing a weighted full-waveform inversion. The weighted full-waveform inversion further includes: weighting a full-waveform inversion gradient with the clipped inverse of the diving wave illumination image; and performing the full-waveform inversion using the weighted gradient.

Abstract: A process for the separation of the components of a solid/liquid mixture. The process Includes the use of a rotary pressure filter apparatus having improved capacity.

Abstract: A method for recalculating the solvent power of a light oil, SP(LO recalculated), is provided.

Abstract: A process for manufacturing a carboxylic acid is provided, in one aspect, the process comprises oxidizing a feedstock comprising a substituted aromatic hydrocarbon to form a liquid-phase aromatic carboxylic acid; crystallizing at least a portion of the liquid-phase aromatic carboxylic acid in the presence of oxygen and an oxidation catalyst in a first crystallizer to form solid aromatic carboxylic acid, under reaction conditions suitable to oxidize unreacted feedstock to form additional aromatic carboxylic acid; and crystallizing at least a portion of the first crystallization effluent in the presence of oxygen and an oxidation catalyst in a second crystallizer to form additional solid aromatic carboxylic acid, under reaction conditions suitable to oxidize unreacted feedstock to form additional aromatic carboxylic acid, wherein the oxygen is present in a gaseous phase inside the second crystallizer in an amount of no more than 11% by volume on a dry basis.

Abstract: A method of performing single trace inversion to characterize changes in a subsurface region includes obtaining a base seismic trace and a monitor seismic trace of the subsurface region at different respective times. The method includes generating a predicted monitor seismic trace from the base seismic trace by a process including applying a time shift to the base seismic trace, the time shift being derived from estimated velocity perturbations occurring between the base seismic trace and the monitor seismic trace, compensating for amplitude changes between the base seismic trace and the monitor seismic trace, wherein the time shift is applied to the amplitude changes, and minimizing a difference between the predicted monitor seismic trace and the monitor seismic trace by iteratively estimating the velocity perturbations to obtain final estimated velocity perturbations. Changes of at least part of the subsurface region may be characterized using the final estimated velocity perturbations.

Abstract: A hydrocarbon production system includes a well at a remote location. The well is configured to produce hydrocarbon production fluids comprising natural gas. The system also includes a turbo-generator coupled to the well and configured to receive the natural gas and produce electricity from the natural gas. In addition, the system includes a high performance computing (HPC) data center coupled to the turbo-generator and configured to be powered by the electricity from the turbo-generator.

Abstract: A method for use in vertical seismic profiling includes: independently and simultaneously shooting a plurality of seismic sources in a plurality of shooting areas to impart seismic signals into a water bottom: receiving reflections of the seismic signals from a subterranean formation beneath the water bottom at a plurality of seismic receivers; and recording the received reflections; wherein, one of the seismic sources and the seismic receivers are disposed in a wellbore in the water bottom.

Abstract: The present invention relates to a method for converting a feed mixture comprising an aromatic C8 mixture of xylenes and ethylbenzene in which the para-xylene content of the xylene portion of the feed is less than equilibrium to produce a product mixture of reduced ethylbenzene content and a greater amount of para-xylene, which method comprises contacting the feed mixture at conversion conditions with a first catalyst having activity for the conversion of ethylbenzene, and with a second catalyst having activity for the isomerization of a xylene.

Abstract: The presently disclosed seismic acquisition technique employs a receiver array and a processing methodology that are designed to attenuate the naturally occurring seismic background noise recorded along with the seismic data during the acquisition. The approach leverages the knowledge that naturally occurring seismic background noise moves with a slower phase velocity than the seismic signals used for imaging and inversion and, in some embodiments, may arrive from particular preferred directions. The disclosed technique comprises two steps: 1) determining from the naturally occurring seismic background noise in the preliminary seismic data a range of phase velocities and amplitudes that contain primarily noise and the degree to which that noise needs to be attenuated, and 2) designing an acquisition and processing method to attenuate that noise relative to the desired signal.

Abstract: A method for predicting the critical solvent power of a visbroken residue stream of interest, CSPVisRes(OI) comprises predicting CSPVisRes(OI) from the critical percentage titrant of an atmospheric residue stream, CPTAR, the atmospheric residue stream being derived from the same crude oil as the visbroken residue stream of interest. A method for predicting the solvent power of a visbroken residue stream of interest, SPVisRes(OI), comprises predicting SPVisRes(OI) from the critical solvent power of the visbroken residue stream, CSPVisRes, and the critical percentage titrant of the visbroken residue stream, CPTVisRes. CPTVisRes is derived from the critical percentage cetane of the visbroken residue stream, CPCVisRes, which, in turn, is calculated from the P-value of the visbroken residue stream. The methods may be used to predict the stability of a fuel oil containing the visbroken residue.

Abstract: In some examples, a method comprises receiving, by a computer system, data from a plurality of equipment of a production facility; displaying, on a display unit of the computer system, a dynamic digital replica of the production facility, wherein accessing a digital replica of one of the plurality of equipment via the dynamic digital replica displays data for the one of the plurality of equipment of the production facility; analyzing the data for the one of the plurality of equipment; and generating, based on the analysis, a report on a health of the one of the plurality of equipment.

Abstract: A method includes receiving image data that is to be recognized by the at least one neural network. The image data is representative of a fault within a subsurface volume. The image data includes three-dimensional synthetic data. The method also includes generating an output via the at least one neural network based on the received image data. The method also includes comparing the output of the at least one neural network with a desired output; and modifying the neural network so that the output of the neural network corresponds to the desired output.

Abstract: A device may include a processor that may recover the signals misallocated in the deblending process of seismic data acquired with simultaneous sources. The processor may update the primary signal estimate based at least in part on a separation operation that separates coherence signals from noise signals in an output associated with the residual determined to be remaining energy for separation. The processor may be incorporated into the iterative primary signal estimate of the deblending process or be applied towards preexisting deblending output. In response to satisfying an end condition, the processor may transmit a deblended output that includes the weak coherence signals recovered from the misallocation or error in the primary signal estimate. The processor may also transmit the deblended output for use in generating a seismic image. The seismic image may represent hydrocarbons in a subsurface region of Earth or subsurface drilling hazards.