Abstract: An improved optical fiber distributed acoustic sensor system uses an optical fiber having reflector portions distributed along its length in at least a first portion. The reflector portions are positioned along the fiber separated by a distance that is equivalent to twice the distance an optical pulse travels along the fiber in a single sampling period of the data acquisition opto-electronics within the sensor system. No oversampling of the reflections of the optical pulses from the reflector portions is undertaken. The sampling points for data acquisition in the sensor system are aligned with the reflections that arrive at the sensor system from along the sensing fiber. Adaptive delay componentry adaptively aligns the reflected optical signals (or their electrical analogues) with the sampling points. Control over the sampling points can re-synchronise the sampling points with the returning reflections. Reflection equalisation componentry may reduce the dynamic range of the returning reflections.

Abstract: A process is provided for recovering hydrocarbons, such as heavy oils, from a subterranean reservoir. The process includes providing a subcritical or a supercritical aqueous fluid at a high temperature and high pressure to the underground hydrocarbon reservoir, injecting the aqueous fluid into the reservoir to heat the hydrocarbons in the reservoir, and recovering the heated hydrocarbons from the reservoir. In some cases, the supercritical fluid is also used to upgrade the hydrocarbons and/or facilitate the transportation of the hydrocarbons from the production field to another location, such as a refinery. Advantageously, isentropic expansion may be employed anywhere in the system for a more efficient and effective processes and systems.

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 ?B for the fluid mixture is used for determining drag reduction for a fluid mixture in an oil field or pipeline operation.

Abstract: Data in physical space may be converted to layer space before performing modeling to generate one or more subsurface representations. Computational stratigraphy model representations that define subsurface configurations as a function of depth in the physical space may be converted to the layer space so that the subsurface configurations are defined as a function of layers. Conditioning information that defines conditioning characteristics as the function of depth in the physical space may be converted to the layer space so that the conditioning characteristics are defined as the function of layers. Modeling may be performed in the layer space to generate subsurface representations within layer space, and the subsurface representations may be converted into the physical space.

Abstract: Disclosed are compositions and methods for use in oil and gas operations.

Abstract: A set of alarm criteria for a drilling tool may be obtained. Individual alarm criterion of the set of alarm criteria may be satisfied based on the drilling tool operating with a set of operating characteristics corresponding to the individual alarm criterion. The set of alarm criteria may include two or more of a tight-hole alarm criterion, a washout alarm criterion, a packoff alarm criterion, a weight-stacking alarm criterion, a delta-torque alarm criterion, a torque alarm criterion, a rate-of-penetration alarm criterion, a reamer-tension-compression alarm criterion, a running-speed alarm criterion, a drag alarm criterion, and/or a pipe-movement alarm criterion. An alarm event corresponding to an alarm criterion may be detected based on the operating characteristic(s) of the drilling tool matching the set of operating characteristics corresponding to the alarm criterion. Responsive to detection of the alarm event, an alarm for the alarm event may be generated.

Abstract: Provided is a hydro-regeneration catalyst system, comprising: (a) a first graded bed comprising a guard bed material; and (b) a second graded bed, fluidly connected to the first graded bed, comprising a noble metal catalyst on a support having mesopores and macropores; wherein the noble metal catalyst has an average pore diameter of 20 to 1,000 nm (0.02 to 1 ?m), a total pore volume of greater than 0.80 cc/g, and a macropore volume of 0.10 to 0.50 cc/g. Also provided is a guard bed system, comprising: (a) a first guard bed comprising a first adsorbent having 10 ?m or larger pores with an average pore diameter of 100 to 1,000 ?m; and (b) a second guard bed fluidly connected to the first guard bed, comprising a second adsorbent material having mesopores and macropores with a second average pore diameter of 20 to 1,000 nm.

Abstract: A family of new crystalline molecular sieves designated SSZ-91 is disclosed, as are methods for making SSZ-91 and uses for SSZ-91. Molecular sieve SSZ-91 is structurally similar to sieves falling within the ZSM-48 family of molecular sieves, and is characterized as: (1) having a low degree of faulting, (2) a low aspect ratio that inhibits hydrocracking as compared to conventional ZSM-48 materials having an aspect ratio of greater than 8, and (3) is substantially phase pure.

Abstract: A method for quantitatively evaluating multiple computer-based plate tectonic models for application in a geographic region of interest, in some embodiments, comprises: selecting a plurality of computer-based plate tectonic models; using multiple computer-based plate tectonic models to generate one or more predictions for one or more geological parameters; obtaining observational data for each of said one or more geological parameters; for each of said one or more geological parameters, quantitatively comparing the predictions and the observational data to determine model rankings; and displaying said model rankings on a computer display.

Abstract: Embodiments of determining proppant distribution for a plurality of clusters within a fracture stage of a wellbore are provided herein. The embodiments include performing computational fluid dynamics modeling on at least a portion of a wellbore without any openings and a portion of the wellbore comprising at least one opening along a single azimuth to determine proppant efficiency for the at least one opening along the single azimuth while simulating flow of fluid, proppant, or any combination thereof through the wellbore, an equilibrium proppant concentration profile for the portion of the wellbore without any openings, and an equilibrium velocity profile for the portion of the wellbore without any openings. The embodiment further comprises determining proppant efficiency for at least one other opening of the wellbore at a different azimuth, generating a model that correlates the single azimuth among other items, and using the model to determine the proppant distribution.

Abstract: Provided herein is a unique process that prepares a saturated hydrocarbon mixture with well-controlled structural characteristics that address the performance requirements driven by the stricter environmental and fuel economy regulations for automotive engine oils. The process allows for the branching characteristics of the hydrocarbon molecules to be controlled so as to consistently provide a composition that has a surprising CCS viscosity at ?35° C. (ASTM D5329) and Noack volatility (ASTM D5800) relationship. The process comprises providing a specific olefinic feedstock, oligomerizing in the presence of a BF3 catalyst, and hydroisomerizing in the presence of a noble-metal impregnated, 10-member ring zeolite catalyst.

Abstract: One embodiment of a wellbore to fracture connectivity apparatus comprises an opening portion representing an opening in a wellbore for receiving fluid, proppant, or any combination thereof to generate at least one fracture in a formation; a fracture portion representing the at least one fracture in the formation; and a coupling portion representing wellbore to fracture connectivity between the opening portion and the fracture portion. The coupling portion couples the opening portion and the fracture portion.

Abstract: Embodiments of determining a hydraulic fracture completion configuration for a wellbore that extends through a subterranean formation are provided herein. Embodiments of performing a hydraulic fracturing operation on a wellbore that extends through a subterranean formation are also provided herein.

Abstract: Acoustic transducers generate and receive acoustic signals at multiple locations along a surface of rigid structure, wherein longitudinal spacing between transducer locations define measurement zones. Acoustic signals with chosen amplitude-time-frequency characteristics excite multiple vibration modes in the structure within each zone. Small mechanical changes in inspection zones lead to scattering and attenuation of broadband acoustic signals, which are detectable as changes in received signal characteristics as part of a through-transmission technique. Additional use of short, narrowband pulse acoustic signals as part of a pulse-echo technique allows determination of the relative location of the mechanical change within each zone based on the differential delay profiles. For accurate acoustic modeling and simulation, the mesh size, time step, time delay, and time-window size are optimized.

Abstract: A method for determining water-filled porosity and water salinity in a well includes obtaining complex dielectric permittivity of earth formations, either from dielectric measurements representative of well cores, or from dielectric well logs; selecting a dielectric mixing law for the index number m; plotting a m-th root of complex dielectric permittivity at a specified frequency in the complex domain, wherein m is an index number; determining a matrix permittivity, a water salinity, and a water-filled porosity based on the complex dielectric permittivity and the dielectric mixing law; and displaying the water salinity and the water-filled porosity.

Abstract: A method is described for ways to generate a Fraction of Sand (Fsand) estimate and net-to-gross (NTG) estimate of sand in a formation using a machine-learning algorithm such as a neural network based on borehole image logs. The method may use the Fsand and other information to estimate hydrocarbons in place in a subsurface formation. The method may be executed by a computer system.

Abstract: Embodiments of the disclosure include swellable smart gel sealants. In certain embodiments, the smart gel sealants reversibly swell when exposed to a certain trigger, such as temperature or pH. In specific embodiments, the smart gel is disposed within voids in a well and triggered to swell in order to seal the voids. One application of the smart gel sealant is to seal the casing of a well against the leakage of gas, such as CO2.

Abstract: The present invention pertains to improved processes and catalysts for aromatization. The processes generally contacting a feed stream comprising a naphtha fraction having a C6 to C8 content with a catalyst pellet composition to form aromatic hydrocarbons. The catalyst pellet composition generally comprises a plurality of cylindrical pellets each pellet comprising a Group VIII metal on a zeolite. The pellets may have (a) a plurality of holes passing through the length of the cylindrical pellets, (b) a dome-shaped top and bottom, and (c) a plurality of semi-circular grooves along the length of the exterior of the cylinder.

Abstract: An apparatus (10) and method for performing nonlinear elasticity measurements using the dynamic acousto-elasticity technique (DAET) at simulated subsurface conditions in the laboratory, are described. The current state-of-the-art for measuring nonlinear elasticity parameters using DAET is limited to ambient pressure conditions on the bench-top. The present invention permits nonlinear parameter measurements at controlled sample internal fluid pore pressures (52) and external confining stress (44), (50) conditions.

Abstract: Data in physical space may be converted to layer space before performing modeling to generate one or more subsurface representations. Computational stratigraphy model representations that define subsurface configurations as a function of depth in the physical space may be converted to the layer space so that the subsurface configurations are defined as a function of layers. Conditioning information that defines conditioning characteristics as the function of depth in the physical space may be converted to the layer space so that the conditioning characteristics are defined as the function of layers. Modeling may be performed in the layer space to generate subsurface representations within layer space, and the subsurface representations may be converted into the physical space.